FERC Form

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

NOTES TO FINANCIAL STATEMENTS

Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement.
Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock.
For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Commission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof.
Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts.
Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein.
For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred.
Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.

The notes provided herein were derived from the notes disclosed in the Annual Report of Exelon Corporation (Exelon) on Form 10-K for the fiscal year ended December 31, 2024. The notes presented herein were modified to include information relevant to Commonwealth Edison Company (ComEd). All amounts presented within the footnotes are rounded in millions unless otherwise noted.

1. Significant Accounting Policies

Description of Business

ComEd was organized in the State of Illinois in 1913 as a result of the merger of Cosmopolitan Electric Company into the original corporation named Commonwealth Edison Company, which was incorporated in 1907. ComEd is engaged principally in the purchase and regulated retail sale of electricity and the provision of transmission and distribution services to a diverse base of residential, commercial, industrial and wholesale customers in Northern Illinois, including the City of Chicago. ComEd’s retail service territory has an area of approximately 11,450 square miles and an estimated population of 9.2 million. The service territory includes the City of Chicago, an area of about 225 square miles with an estimated population of 2.6 million. ComEd has approximately 4.1 million customers.

Basis of Presentation

ComEd is a principal indirect subsidiary of Exelon, which owns more than 99% of ComEd’s common stock.

Accounting policies for regulated operations are in accordance with those prescribed by the regulatory authorities having jurisdiction, principally the Illinois Commerce Commission (ICC) under state public utility laws and the Federal Energy Regulatory Commission (FERC). The accompanying financial statements have been prepared in accordance with the accounting requirements of FERC as set forth in the Uniform System of Accounts (USOA) and accounting releases, which differ from accounting principles generally accepted in the United States (GAAP). The principal differences from GAAP include the exclusions of current maturities of long-term debt from current liabilities, the exclusion of debt issuance costs from long-term debt, the exclusion of restricted cash within Cash and cash equivalents in the Statement of Cash Flows, the requirement to report deferred tax assets and liabilities separately rather than as a single amount, the classification of accrued taxes as assets and liabilities rather than a net amount, the exclusion of FIN 48 liabilities related to temporary income tax differences, the derecognition of operating leases from the balance sheet, the classification of cloud computing costs, and the classification of certain other assets and liabilities as current instead of noncurrent.

ComEd’s investments in Commonwealth Edison Company of Indiana, Inc. (ComEd of Indiana), RITELine Illinois, LLC and EdiSun, LLC are accounted for under the equity method of accounting in accordance with the USOA. These entities are consolidated in ComEd’s GAAP financial statements.

ComEd’s investment in ComEd Financing III is accounted for under the equity method of accounting in accordance with the USOA. This entity is not consolidated in ComEd’s GAAP financial statements.

Revision of Previously Issued Financial Statements

Management identified an error in ComEd's previously issued financial statements attributable to the presentation of recapitalized fleet depreciation in the Statement of Cash Flows. As a result of the error, ComEd's Statement of Cash Flows for the year ended December 31, 2023 reflected an overstatement of the cash outflow attributable to Gross additions to utility plant (less nuclear fuel) of $40 million, and an equal and offsetting understatement of the cash outflow attributable to Other investing activities. The error did not impact net cash flows provided by operating activities, net cash flows used in investing activities, or net cash flows provided by financing activities for the year ended December 31, 2023. Furthermore, there was no impact on ComEd's Balance Sheet as of December 31, 2023 or Income Statement for the year ended December 31, 2023.

ComEd management has concluded the error was not material to previously issued financial statements. The Statement of Cash Flows for the year ended December 31, 2023 was revised to reflect the correction of the error.

Use of Estimates

The preparation of financial statements in conformity with USOA requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Areas in which significant estimates have been made include, but are not limited to, the accounting for pension and other postretirement employee benefits (OPEB), unbilled energy revenues, allowance for uncollectible accounts, inventory provision, goodwill, and long-lived asset impairments, derivative instruments, fixed asset depreciation, capitalization of indirect construction costs, environmental costs

and other loss contingencies, asset retirement obligations (AROs), and income taxes. Actual results could differ from those estimates.

Regulatory Accounting

For its regulated electric operations, ComEd reflects the effects of cost-based rate regulation in its financial statements, which is required for entities with regulated operations that meet the following criteria: 1) rates are established or approved by a third-party regulator; (2) rates are designed to recover the entities’ cost of providing services or products; and (3) there is a reasonable expectation that rates designed to recover costs can be charged to and collected from customers. ComEd accounts for its regulated operations in accordance with regulatory and legislative guidance from the regulatory authority having jurisdiction, principally the ICC, under state public utility laws and the FERC under various Federal laws. Regulatory assets and liabilities are amortized and the related expense or revenue is recognized in the Statement of Income consistent with the recovery or refund included in customer rates. ComEd's regulatory assets and liabilities as of the balance sheet date are probable of being recovered or settled in future rates. If a separable portion of ComEd's business was no longer able to meet the criteria discussed above, ComEd would be required to eliminate from its financial statements the effects of regulation for that portion, which could have a material impact on its financial statements. See Note 2—Regulatory Matters for additional information.

ComEd treats the impacts of a final rate order received after the balance sheet date but prior to the issuance of the financial statements as a non-recognized subsequent event, as the receipt of a final rate order is a separate and distinct event that has future impacts on the parties affected by the order.

Revenues

Operating Revenues. ComEd’s operating revenues generally consist of revenues from contracts with customers involving the sale and delivery of power and utility revenues from alternative revenue programs (ARP). ComEd recognizes revenue from contracts with customers to depict the transfer of goods or services to customers in an amount that the entities expect to be entitled to in exchange for those goods or services. ComEd's primary sources of revenue include regulated electric tariff sales, distribution and transmission services. At the end of each month, ComEd accrues an estimate for the unbilled amount of energy delivered or services provided to customers.

ComEd records ARP revenue for its best estimate of the electric distribution, energy efficiency, and transmission revenue impacts resulting from future changes in rates that ComEd believes are probable of approval by the ICC and FERC in accordance with its distribution multi-year rate plan, distribution revenue decoupling mechanisms, and formula rate mechanisms. See Note 2—Regulatory Matters for additional information.

Taxes Directly Imposed on Revenue-Producing Transactions. ComEd collects certain taxes from customers such as sales and gross receipts taxes, along with other taxes, surcharges and fees, that are levied by state or local governments on the sale or distribution of electricity. Some of these taxes are imposed on the customer, but paid by ComEd, while others are imposed on ComEd. Where these taxes are imposed on the customer, such as sales taxes, they are reported on a net basis with no impact to the Statement of Income. However, where these taxes are imposed on ComEd, such as gross receipts taxes or other surcharges or fees, they are reported on a gross basis. Accordingly, revenues are recognized for the taxes collected from customers along with an offsetting expense. See Note 14— Supplemental Financial Information for ComEd’s utility taxes that are presented on a gross basis.

Income Taxes

Deferred federal and state income taxes are recorded on significant temporary differences between the book and tax basis of assets and liabilities and for tax benefits carried forward. Investment tax credits have been deferred in ComEd's Balance Sheets and are recognized in book income over the life of the related property. In accordance with USOA, ComEd reports deferred income tax balances arising from temporary differences in Accounts 190, 282 and 283 as appropriate, which differs from the net presentation required by GAAP. See Note 7—Income Taxes for additional information. ComEd recognizes accrued interest related to unrecognized tax benefits in interest expense or interest income in Net Interest Charges and Other Income, respectively on its Statements of Income.

ComEd accounts for uncertain income tax positions using a benefit recognition model with a two-step approach; a more-likely-than-not recognition criterion; and a measurement approach that measures the position as the largest amount of tax benefit that is greater than 50% likely of being realized upon ultimate settlement. If it is not more-likely-than-not that the benefit of the tax position will be sustained on its technical merits, no benefit is recorded. Uncertain tax positions that relate only to timing of when an item is included on a tax return are considered to have met the recognition threshold.

ComEd accounts for uncertain income tax positions in accordance with FERC's guidance on Accounting and Financial Reporting for Uncertainty in Income Taxes, issued in Docket No. AI07-2-000 for FERC reporting purposes. The guidance

requires, among other things, that entities should continue to recognize deferred income taxes for FERC accounting and reporting purposes based on the difference between positions taken in tax returns filed or expected to be filed and amounts reported in financial statements.

Cash and Cash Equivalents

ComEd considers investments purchased with an original maturity of three months or less to be cash equivalents.

Restricted Cash and Cash Equivalents

Restricted cash and cash equivalents represent funds that are restricted to satisfy designated current liabilities. As of December 31, 2024 and 2023, ComEd’s restricted cash and cash equivalents primarily represented cash collateral held from suppliers associated with ComEd’s energy and renewable energy credits (REC) procurement contracts, any over-recovered Renewable Energy Portfolio Standards (RPS) costs and alternative compliance payments received from Retail Electric Suppliers (RES) pursuant to the Future Energy Jobs Act (FEJA), and costs for the remediation of a Manufactured Gas Plant (MGP) site.

Restricted cash and cash equivalents not available to satisfy current liabilities are classified as noncurrent assets. As of December 31, 2024 and 2023, ComEd's noncurrent restricted cash and cash equivalents primarily represented over-recovered RPS costs and alternative compliance payments received from RES pursuant to FEJA and costs for the remediation of an MGP site.

Accumulated Provision for Uncollectible Accounts on Accounts Receivables

The accumulated provision for uncollectible accounts reflects ComEd's best estimate of losses on the customers' accounts receivable balances based on historical experience, current information, and reasonable and supportable forecasts.

The accumulated provision for uncollectible accounts is estimated based on historical loss experience, current conditions, and forward looking risk factors. ComEd's customer accounts are written off consistent with approved regulatory requirements. Adjustments to the accumulated provision for uncollectible accounts are primarily recorded to Operating and maintenance expense on ComEd's Statement of Income or Regulatory assets and liabilities on ComEd's Balance Sheets. See Note 2 — Regulatory Matters for additional information regarding the regulatory recovery of uncollectible accounts expense on customers' accounts receivable.

ComEd has certain non-customer receivables in Other deferred debits and other assets which primarily are with governmental agencies and other high-quality counterparties with no history of default. As such, the accumulated provision for uncollectible accounts related to these receivables is not material. ComEd monitors these balances and will record an allowance if there are indicators of a decline in credit quality. See Note 3 — Accounts Receivable for additional information.

Inventories

Inventory is recorded at the lower of weighted average cost or net realizable value. Provisions are recorded for excess and obsolete inventory. Materials and supplies are generally included in inventory when purchased. Materials and supplies inventory generally includes transmission and distribution materials and are expensed to Operating and maintenance or capitalized to Property, plant, and equipment, as appropriate, when installed or used.

Property, Plant and Equipment

Property, plant and equipment is recorded at original cost. Original cost includes construction-related direct labor and material costs and indirect construction costs including labor and related costs of departments associated with supporting construction activities. When appropriate, original cost also includes allowance for funds used during construction (AFUDC) for regulated property. The cost of repairs and maintenance and minor replacements of property is charged to Operating and maintenance expense as incurred.

Third parties reimburse ComEd for all or a portion of expenditures for certain capital projects. Such contributions in aid of construction costs (CIAC) are recorded as a reduction to Property, plant and equipment, net.

Upon retirement, the cost of property, net of salvage, is charged to accumulated depreciation consistent with the composite and group methods of depreciation. Depreciation expense includes the estimated cost of dismantling and removing plant from service upon retirement. Actual incurred removal costs are applied against a related regulatory liability or recorded to a regulatory asset if in excess of previously collected removal costs.

Capitalized Software. Certain costs, such as design, coding, and testing incurred during the application development stage of software projects that are internally developed or purchased for operational use are capitalized within Property, plant, and

equipment. Similar costs incurred for cloud-based solutions treated as service arrangements are capitalized within Property, plant, and equipment. Such capitalized amounts are amortized ratably over the expected lives of the projects when they become operational, generally not to exceed five years. Certain other capitalized software costs are being amortized over longer lives, based on the expected life or pursuant to prescribed regulatory requirements.

Allowance for Funds Used During Construction (AFUDC). AFUDC is the cost, during the period of construction, of debt and equity funds used to finance construction projects for regulated operations. AFUDC is recorded to construction work in progress and as a non-cash credit to an allowance that is included in interest expense for debt-related funds and other income and deductions for equity-related funds. The rates used for capitalizing AFUDC are computed under a method prescribed by regulatory authorities.

See Note 4 — Property, Plant, and Equipment for additional information.

Depreciation and Amortization

Depreciation is generally recorded over the estimated service lives of property, plant and equipment on a straight-line basis using the group or composite methods of depreciation. The group approach is typically for groups of similar assets that have approximately the same useful lives and the composite approach is used for dissimilar assets that have different lives. Under both methods, a reporting entity depreciates the assets over the average life of the assets in the group. ComEd's depreciation expense includes the estimated cost of dismantling and removing plant from service upon retirement, which is consistent with ComEd's regulatory recovery method. The estimated service lives for ComEd are based on a combination of depreciation studies and historical retirements. See Note 4 — Property, Plant, and Equipment for additional information regarding depreciation.

Amortization of regulatory assets and liabilities is recorded over the recovery or refund period specified in the related legislation or regulatory order or agreement. When the recovery or refund period is less than one year, amortization is recorded to the line item in which the deferred cost or income would have originally been recorded in ComEd's Statement of Income. Amortization of ComEd’s electric distribution and energy efficiency formula rate regulatory assets and ComEd’s transmission formula rate regulatory asset is recorded to Operating revenues.

Amortization of income tax related regulatory assets and liabilities is generally recorded to Income tax expense. Except for the regulatory assets and liabilities discussed above, amortization is generally recorded to Depreciation and amortization in ComEd's Statement of Income when the recovery period is more than one year.

See Note 2 — Regulatory Matters for additional information regarding the amortization of ComEd’s regulatory assets and liabilities.

Asset Retirement Obligations

ComEd estimates and recognizes a liability for its legal obligation to perform asset retirement activities even though the timing and/or methods of settlement may be conditional on future events. ComEd updates its AROs either annually or on a rotational basis at least once every three years, based on a risk profile, unless circumstances warrant more frequent updates. The updates factor in new cost estimates, credit-adjusted, risk-free rates (CARFR) and escalation rates, and the timing of cash flows. AROs are accreted throughout each year to reflect the time value of money for these present value obligations through an increase to regulatory assets. See Note 5 — Asset Retirement Obligations for additional information.

Guarantees

If necessary, ComEd recognizes a liability at the time of issuance of a guarantee for the fair value of the obligations it has undertaken.

The liability is reduced or eliminated as ComEd is released from risk under the guarantee. Depending on the nature of the guarantee, ComEd's release from risk may be recognized only upon the expiration or settlement of the guarantee or by a systematic and rational amortization method over the term of the guarantee. See Note 12—Commitments and Contingencies for additional information.

Asset Impairments

Long-Lived Assets. ComEd evaluates the carrying value of its long-lived assets for recoverability whenever events or changes in circumstances indicate that the carrying value of those assets may not be recoverable. Indicators of impairment may include specific regulatory disallowance, abandonment, or plans to dispose of a long-lived asset significantly before the end of its useful life. When the estimated undiscounted future cash flows attributable to the long-lived asset may not be recoverable, the amount of the impairment loss is determined by measuring the excess of the carrying amount of the long-lived asset over its fair value.

Goodwill. Goodwill represents the excess of the purchase price paid over the estimated fair value of the net assets acquired and liabilities assumed in the acquisition of a business. Goodwill is not amortized but is assessed for impairment at least annually or on an interim basis if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. See Note 6 - Intangible Assets for additional information.

Derivative Financial Instruments

Derivatives are recognized on the balance sheet at their fair value unless they qualify for certain exceptions, including the normal purchases and normal sales (NPNS) exception. For derivatives intended to serve as economic hedges, which are not designated for hedge accounting, changes in fair value each period are recognized in earnings or as a regulatory asset or liability. Amounts recognized in earnings are recorded in Operating revenue, Purchased power, or Interest expense in the Statement of Income based on the activity the transaction is economically hedging. Changes in fair value are also recorded as a regulatory asset or liability when there is an ability to recover or return the associated costs or benefits in accordance with regulatory requirements. Cash inflows and outflows related to derivative instruments are included as a component of operating, investing or financing cash flows in the Statement of Cash Flows, depending on the nature of each transaction. See Note 2 — Regulatory Matters and Note 9 - Derivative Financial Instruments for additional information.

Retirement Benefits

ComEd participates in Exelon’s defined benefit pension plans and OPEB plans.

The plan obligations and costs of providing benefits under these plans are measured as of December 31. The measurement involves various factors, assumptions, and accounting elections. The impact of assumption changes or experience different from that assumed on pension and OPEB obligations is recognized over time rather than immediately recognized in the Statement of Income. Gains or losses in excess of the greater of ten percent of the projected benefit obligation or the market-related value of plan assets are amortized over the expected average remaining service period of plan participants. See Note 8— Retirement Benefits for additional information.

New Accounting Pronouncements

New Accounting Standards Issued and Not Yet Adopted as of December 31, 2024

The following new authoritative accounting guidance issued by the FASB has not yet been adopted and reflected by ComEd in their financial statements as of December 31, 2024. Unless otherwise indicated, ComEd is currently assessing the impacts such guidance may have (which could be material) in their Balance Sheet, Statement of Income, Statement of Cash Flows and disclosures, as well as the potential to early adopt where applicable. ComEd has assessed other FASB issuances of new standards which are not listed below given the current expectation that such standards will not significantly impact ComEd's financial reporting.

Improvement to Income Tax Disclosures (Issued December 2023). Provides additional disclosure requirements related to the effective tax rate reconciliation and income taxes paid. Under the revised guidance for the effective tax reconciliations, entities would be required to disclose: (1) eight specific categories in the effective tax rate reconciliation in both percentages and reporting currency amount, (2) additional information for reconciling items over a certain threshold, (3) explanation of individual reconciling items disclosed, and (4) provide a qualitative description of the state and local jurisdictions that contribute to the majority of the state income tax expense. For each annual period presented, the new standard requires disclosure of the year-to-date amount of income taxes paid (net of refunds received) disaggregated by federal, state, and foreign. It also requires additional disaggregated information on income taxes paid (net of refunds received) to an individual jurisdiction equal to or greater than 5% of total income taxes paid (net of refunds received). The standard is effective January 1, 2025, with early adoption permitted.

Disaggregation of Income Statement Expenses (Issued November 2024). Provides additional disclosure requirements related to relevant expense captions of income statement expense line items. The revised guidance requires a new tabular disclosure of disaggregated income statement expenses including a break out of (1) purchases of inventory, (2) employee compensation, (3) depreciation, (4) intangible asset amortization, (5) depreciation, depletion, and amortization recognized as part of oil and gas producing activities included in each relevant expense line item on the income statement. The tabular disaggregation should include certain amounts already required to be disclosed under GAAP elsewhere. Any remaining amounts not separately disaggregated quantitatively should include a qualitative description. Additionally, on an annual basis, the standard requires disclosure of management’s definition of selling expenses and the amount of expense. The standard is effective January 1, 2027, with early adoption permitted. ComEd is currently assessing the impacts of this standard.

2. Regulatory Matters

The following matters below discuss the status of material regulatory and legislative proceedings of ComEd.

Distribution Base Rate Case Proceedings

The following table shows the completed distribution base rate case proceedings in 2024.

Completed Distribution Base Rate Case Proceedings

Jurisdiction

Filing Date

Service

Requested Revenue Requirement Increase

Approved Revenue Requirement Increase

Approved ROE

Approval Date

Rate Effective Date

Illinois

January 17, 2023(a)

Electric

1,487

1,045

8.905%

December 19, 2024

January 1, 2024

April 26, 2024 (amended on September 11, 2024)(b)

624

623

9.89%

October 31, 2024

January 1, 2025

__________

(a) Reflects a four-year cumulative multi-year rate plan (MRP) for January 1, 2024 to December 31, 2027. The MRP was originally approved by the ICC on December 14, 2023 and was subsequently amended on January 10, 2024, April 18, 2024 and December 19, 2024. The December 19, 2024 order provided a total revenue requirement increase of $1.045 billion inclusive of rate increases of approximately $752 million in 2024, $80 million in 2025, $102 million in 2026, and $111 million in 2027.

(b) On October 31, 2024, the Delivery Reconciliation Amount for 2023 defined in Rider Delivery Service Pricing Reconciliation (Rider DSPR) was approved. Rider DSPR allows for the reconciliation of the revenue requirement in effect in the final years in which formula rates are determined and until such time as new rates are established under ComEd's approved MRP. The 2024 order reconciled the delivery service rates in effect in 2023 with the actual delivery service costs incurred in 2023. The reconciliation revenue requirement provides for a weighted average debt and equity return on distribution rate base of 7.02%, inclusive of an allowed ROE of 9.89%, reflecting the monthly yields on 30-year treasury bonds plus 580 basis points.

Transmission Formula Rates

ComEd’s transmission rate is established based on a FERC-approved formula. ComEd is required to file an annual update to the FERC-approved formula on or before May 15, with the resulting rate effective on June 1 of the same year. The annual update is based on prior year actual costs and current year projected capital additions (initial year revenue requirement). The update also reconciles any differences between the revenue requirement in effect beginning June 1 of the prior year and actual costs incurred for that year (annual reconciliation).

For 2024, the following increases/(decreases) were included in ComEd’s electric transmission formula rate update:


Filing Date(a)	Initial Revenue Requirement Increase		Annual Reconciliation Decrease		Total Revenue Requirement Increase		Allowed Return on Rate Base(b)		Allowed ROE(c)
April 24, 2024	$	32	$	(12)	$	20	8.14	%	11.50	%

__________

(a)All rates are effective June 1, 2024 - May 31, 2025, subject to review by interested parties pursuant to review protocols of ComEd's tariff.

(b)Represents the weighted average debt and equity return on transmission rate bases.

(c)The rate of return on common equity includes a 50-basis-point incentive adder for being a member of a Regional Transmission Organization (RTO).

Other State Regulatory Matters

Illinois Regulatory Matters

Clean and Equitable Jobs Act (CEJA). On September 15, 2021, the Governor of Illinois signed into law CEJA. CEJA includes, among other features, (1) procurement of CMCs from qualifying nuclear-powered generating facilities, (2) a requirement to file a general rate case or a new four-year MRP no later than January 20, 2023 to establish rates effective after ComEd’s existing performance-based distribution formula rate sunsets, (3) requirements that ComEd and the ICC initiate and conduct various regulatory proceedings on subjects including ethics, spending, grid investments, and performance metrics.

ComEd Electric Distribution Rates

ComEd filed, and received approval for, its last performance-based electric distribution formula rate update under Energy Infrastructure Modernization Act (EIMA) in 2022; those rates were in effect throughout 2023.

On February 3, 2022, the ICC approved a tariff that established the process under which ComEd reconciled its 2022 and 2023 rate year revenue requirements with actual costs. Those reconciliation amounts were determined using the same process used for prior reconciliations under the performance-based electric distribution formula rate. Using that process, for the rate

years 2022 and 2023 ComEd will ultimately collect revenues from customers reflecting each year’s actual recoverable costs, year-end rate base, and a weighted average debt and equity return on distribution rate base, with the ROE component based on the annual average of the monthly yields of the 30-year U.S. Treasury bonds plus 580 basis points. In April 2023, ComEd filed its first petition with the ICC to reconcile its 2022 actual costs with the approved revenue requirement that was in effect in 2022; the final order was issued on November 30, 2023, for rates beginning January 2024. On April 26 2024, ComEd filed its petition with the ICC to reconcile its 2023 actual costs with the approved revenue requirement that was in effect in 2023; the final order was issued on October 31, 2024, for rates beginning January 2025.

Beginning in 2024, ComEd started recovering from retail customers, subject to certain exceptions, the costs it incurs to provide electric delivery services either through its electric distribution rate or other recovery mechanisms authorized by CEJA. On January 17, 2023, ComEd filed a petition with the ICC seeking approval of a MRP for 2024-2027. The MRP supports a multi-year grid plan (Grid Plan), also filed on January 17, covering planned investments on the electric distribution system within ComEd’s service area through 2027. Costs incurred during each year of the MRP are subject to ICC review and the plan’s revenue requirement for each year will be reconciled with the actual costs that the ICC determines are prudently and reasonably incurred for that year. The reconciliation is subject to adjustment for certain costs, including a limitation on recovery of costs that are more than 105% of certain costs in the previously approved MRP revenue requirement, absent a modification of the rate plan itself. Thus, for example, the rate adjustments necessary to reconcile 2024 revenues to ComEd’s actual 2024 costs incurred would take effect in January 2026 after the ICC’s review during 2025.

On December 14, 2023, the ICC issued a final order. The ICC rejected ComEd’s Grid Plan as non-compliant with certain requirements of CEJA and required ComEd to file a revised Grid Plan. In the absence of an approved Grid Plan, the ICC set ComEd’s forecast revenue requirements for 2024-2027 based on ComEd's approved year-end 2022 rate base. This resulted in a total cumulative revenue requirement increase of $501 million, a $986 million total revenue reduction from the requested cumulative revenue requirement increase but remains subject to annual reconciliation in accordance with CEJA. The final order approved the process and formulas associated with the MRP reconciliation mechanisms. The ICC's December 2023 order also denied ComEd's ability to earn a return on its pension asset.

On December 22, 2023, ComEd filed an application for rehearing on several findings in the final order including the use of the 2022 year-end rate base to establish forecast revenue requirements for 2024-2027, ROE, pension asset return, and capital structure. On January 10, 2024, ComEd’s application for rehearing was denied on all issues except for the order’s use of the 2022 year-end rate base. On April 18, 2024, the ICC issued its final order on rehearing, which approved the use of the forecasted year-end 2023 rate base that resulted in increased revenue requirements for 2024-2027. These revenue requirements determined during the rehearing process established base revenue requirements until the ICC approved the Refiled Grid Plan on December 19, 2024.

On January 10, 2024, ComEd also filed an appeal in the Illinois Appellate Court of the issues on which rehearing was denied, including but not limited to the allowed ROE, 50% equity ratio, and denial of a return on ComEd’s pension asset. There is no deadline by when the appellate court must rule. On March 13, 2024, ComEd filed its Refiled Grid Plan with supporting testimony and schedules with the ICC and subsequently on March 15, 2024, ComEd also filed a petition to adjust its MRP to authorize increased rates consistent with the Refiled Grid Plan. On December 19, 2024, the ICC approved the Refiled Grid Plan and adjusted the approved MRP with rates effective on January 1, 2025. The final approved MRP, as adjusted, which reflects the Refiled Grid Plan, resulted in a total cumulative revenue requirement increase of $1.045 billion over the 2024-2027 plan years and remains subject to annual reconciliations in accordance with CEJA. ComEd filed timely requests for rehearing and an appeal of this order, again limited to the on which rehearing of the December 2023 order was denied, including the allowed ROE, 50% equity ratio, and denial of a return on ComEd's pension asset.

In January 2022, ComEd filed a request with the ICC proposing performance metrics that would be used in determining ROE incentives and penalties in the event ComEd filed a MRP in January 2023. On September 27, 2022, the ICC issued a final order approving seven performance metrics that provide symmetrical performance adjustments of 32 total basis points to ComEd’s rate of return on common equity based on the extent to which ComEd achieves the annual performance goals. On November 10, 2022, the ICC granted ComEd's application for rehearing, in part. On April 5, 2023, the ICC issued its final order on rehearing for the performance and tracking metrics proceeding, in which the ICC declined to adopt ComEd's proposed modifications to the reliability and peak load reduction performance metrics. Efforts are underway to implement the performance metrics, which took effect on January 1, 2024. ComEd will make its initial filing in 2025 to assess performance achieved under the metrics in 2024, and to determine any ROE adjustment, which would take effect in 2026. In 2024, ComEd has recognized an estimate of the impact of the performance metrics' adjustment.

Carbon Mitigation Credit

CEJA establishes decarbonization requirements for Illinois as well as programs to support the retention and development of emissions-free sources of electricity. ComEd is required to purchase CMCs from participating nuclear-powered generating facilities between June 1, 2022 and May 31, 2027. The price to be paid for each CMC was established through a competitive bidding process that included consumer-protection measures that capped the maximum acceptable bid amount and a formula that reduces CMC prices by an energy price index, the base residual auction capacity price in the ComEd zone of PJM, and the monetized value of any federal tax credit or other subsidy if applicable. The seller has not provided notification to ComEd or the Illinois Power Agency (IPA) that any subsidies or tax credits, such as nuclear production tax credits that became available for electricity generated beginning January 1, 2024, have been monetized and the IPA did not adjust the CMC price paid by ComEd in 2024. The consumer protection measures contained in CEJA will result in net payments to ComEd ratepayers if the energy index, the capacity price and applicable federal tax credits or subsidy exceed the CMC contract price. Beginning with the June 2022 monthly billing period, ComEd began issuing credits and/or charges to its retail customers under its CMC rider, the Rider Carbon-Free Resource Adjustment (Rider CFRA). A regulatory asset is recorded for the difference between ComEd's costs associated with the procurement of CMCs from participating nuclear power generating facilities and revenues received from customers. The balance as of December 31, 2024 is $179 million.

Under CEJA, the costs of procuring CMCs, including carrying costs, are recovered through Rider CFRA. As originally approved by the ICC, Rider CFRA provides for an annual reconciliation and true-up to actual costs incurred or credits received by ComEd to purchase CMCs, with any difference to be credited to or collected from ComEd’s retail customers in subsequent periods. The difference between the net payments to (or receivables from) ComEd ratepayers and the credits received by ComEd to purchase CMCs is recorded to Purchased power expense with an offset to the regulatory asset (or regulatory liability). On December 21, 2022, ComEd filed an amendment to Rider CFRA proposing that it recover costs or provide credits faster than the tariff allows, implement monthly reconciliations, and allow ComEd to adjust Rider CFRA rates based not only on anticipated differences but also past payments or credits, and implement monthly reconciliations beginning with the June 2023 delivery period. The ICC approved the proposal on January 19, 2023. In addition, on March 24, 2023, ComEd submitted revisions to Rider CFRA which clarified the methodology for calculating interest to be included in the annual reconciliation associated with the June 2022 through May 2023 delivery year. The ICC approved the proposal on April 20, 2023. On February 2, 2024, ComEd filed a petition with the ICC to initiate the reconciliation proceeding for the costs incurred in connection with the procurement of CMCs during the delivery year beginning June 1, 2022 and extending through May 31, 2023.

Excess Deferred Income Taxes

The ICC initiated a docket to accelerate and fully credit to customers TCJA unprotected property-related EDIT no later than December 31, 2025. On July 7, 2022, the ICC issued a final order on the schedule for the acceleration of EDIT amortization, adopting the proposal as submitted by several parties, including ComEd, ICC Staff, the Illinois Attorney General's Office, and the Citizens Utility Board. EDIT amortization will be credited to customers through a new rider from January 1, 2023 through December 31, 2025.

Energy Efficiency

CEJA extends ComEd’s current cumulative annual energy efficiency MWh savings goals through 2040, adds expanded electrification measures to those goals, increases low-income commitments and adds a new performance adjustment to the energy efficiency formula rate. ComEd expects its annual spend to increase in 2023 through 2040 to achieve these energy efficiency MWh savings goals, which is deferred as a separate regulatory asset that is recovered through the energy efficiency formula rate over the weighted average useful life, as approved by the ICC, of the related energy efficiency measures.

Energy Efficiency Formula Rate. FEJA allows ComEd to defer energy efficiency costs (except for any voltage optimization costs which are recovered through electric distribution rates) as a separate regulatory asset that is recovered through the energy efficiency formula rate over the weighted average useful life, as approved by the ICC, of the related energy efficiency measures. ComEd earns a return on the energy efficiency regulatory asset at a rate equal to a weighted average cost of capital, which is based on a year-end capital structure and a statutorily-based formula based on long-term treasury debt. The ROE that ComEd earns on its energy efficiency regulatory asset is subject to a maximum downward or upward adjustment of 200 basis points if ComEd’s cumulative persisting annual MWh savings falls short of or exceeds specified percentage benchmarks of its annual incremental savings goal. ComEd is required to file an update to its energy efficiency formula rate on or before June 1st each year, with resulting rates effective in January of the following year. The annual update is based on projected rate year energy efficiency costs, PJM capacity revenues, and the projected year-end regulatory asset balance less any related deferred income taxes (initial year revenue requirement). The update also reconciles any differences between the revenue requirement in effect for the prior year and actual costs incurred from the year (annual reconciliation). The approved energy efficiency formula rate also provides for revenue decoupling provisions.

During 2024, the ICC approved the following total increases in ComEd's requested energy efficiency revenue requirement:


Filing Date	Requested Revenue Requirement Increase		Approved Revenue Requirement Increase(a)		Approved ROE		Approval Date	Rate Effective Date
May 30, 2024	$	58	$	58	9.89	%	December 5, 2024	January 1, 2025

_________

(a)ComEd's 2025 approved revenue requirement above reflects an increase of $66 million for the initial year revenue requirement for 2025 and a decrease of $8 million related to the annual reconciliation for 2023. The revenue requirement for 2025 provides for a weighted average debt and equity return on the energy efficiency regulatory asset and rate base of 7.02% inclusive of an allowed ROE of 9.89%, reflecting the monthly average yields for 30-year treasury bonds plus 580 basis points. The revenue requirement for the 2023 reconciliation year provides for a weighted average debt and equity return on the energy efficiency regulatory asset and rate base of 7.24% inclusive of an allowed ROE of 10.34%, which includes an upward performance adjustment that increased the ROE. The performance adjustment can either increase or decrease the ROE based upon the achievement of energy efficiency savings goals. See table below for ComEd's regulatory assets associated with its energy efficiency formula rate.

Other Federal Regulatory Matters

FERC Audit. ComEd is subject to periodic audits and investigations by FERC. FERC’s Division of Audits and Accounting initiated a nonpublic audit of ComEd in April 2021 evaluating ComEd’s compliance with (1) approved terms, rates and conditions of its federally regulated service; (2) accounting requirements of the Uniform System of Accounts; (3) reporting requirements of the FERC Form 1; and (4) the requirements for record retention. The audit period extended back to January 1, 2017.

On July 27, 2023, FERC issued a final audit report which included, among other things, findings and recommendations related to ComEd's methodology regarding the allocation of certain overhead costs to capitalized construction costs under FERC regulations, including a suggestion that refunds may be due to customers for amounts collected in previous years. On August 28, 2023, ComEd filed a formal notice of the issues it contested within the audit report. On December 14, 2023, FERC appointed a settlement judge for the contested overhead allocation findings and set the matter for a trial-type hearing. That hearing process was held in abeyance while a formal settlement process, which began in February 2024, took place.

On July 30, 2024, ComEd reached an agreement in principle on the contested overhead allocation finding. As a result of the settlement process, ComEd recorded a charge for the probable disallowance of $70 million of certain currently capitalized construction costs to operating expenses, which are not expected to be recovered in future rates. The final settlement is subject to FERC approval. The existing loss estimate is reflected in ComEd's financial statements as of December 31, 2024. ComEd and FERC staff jointly filed the settlement agreement with FERC for approval on February 11, 2025.

Regulatory Assets and Liabilities

Regulatory assets represent incurred costs that have been deferred because of their probable future recovery from customers through regulated rates. Regulatory liabilities represent the excess recovery of costs or accrued credits that have been deferred because it is probable such amounts will be returned to customers through future regulated rates or represent billings in advance of expenditures for approved regulatory programs.

The following tables provide information about the regulatory assets and liabilities of ComEd as of December 31, 2024 and 2023.


Regulatory Assets (Account 182.3):	December 31, 2024		December 31, 2023
AMI programs - legacy meters	$	13	$	28
Asset retirement obligations	112		104
Carbon mitigation credit	179		673
COVID-19	3		11
Deferred income taxes	291		284
Electric distribution formula rate annual reconciliations	554		787
Electric distribution formula rate significant one-time events	98		89
Energy efficiency costs	1,890		1,691
MGP remediation costs	275		286
Multi-year plan reconciliations	81		—
Renewable energy	131		134
Uncollectible accounts expense	126		78
Zero emissions program	4		58
Other	240		174
Total Regulatory Assets	$	3,997	$	4,397

Regulatory Liabilities (Account 254):	December 31, 2024		December 31, 2023
Decommissioning the Regulatory Agreement Units	$	3,780	$	2,954
Deferred income taxes	1,891		2,178
Electric energy costs	12		5

Renewable portfolio standards costs	1,369		1,102
Transmission formula rate annual reconciliations	—		14
Other	1		1
Total Regulatory Liabilities	$	7,053	$	6,254

Descriptions of the regulatory assets and liabilities included in the tables above are summarized below, including their recovery and amortization periods.


Line Item	Description	End Date of Remaining Recovery/Refund Period	Return
AMI programs - Legacy Meters	Represents early retirement costs of legacy meters.	2028	Yes
Asset retirement obligations	Represents future legally required removal costs associated with existing AROs.	Over the life of the related assets.	Yes, once the removal activities have been performed.
Carbon mitigation credit	Represents CMC procurement costs and credits as well as reasonable costs ComEd has incurred to implement and comply with the CMC procurement process.	2025	No
COVID-19	Represents incremental credit losses and direct costs related to COVID-19 incurred primarily in 2020. Direct costs consistent primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.	2025	Yes


Line Item	Description	End Date of Remaining Recovery/Refund Period	Return
Decommissioning the Regulatory Agreement Units	Represents estimated excess funds at the end of decommissioning the Regulatory Agreement Units. See below regarding Decommissioning the Regulatory Agreement Units for additional information.	Not currently being refunded.	No
Deferred income taxes	Represents deferred income taxes that are recoverable or refundable through customer rates, primarily associated with accelerated depreciation, the equity component of AFUDC, and the effects of income tax rate changes, including those resulting from the TCJA.	Amounts are recoverable over the period in which the related deferred income taxes reverse, which is generally based on the expected life of the underlying assets. For TCJA, generally refunded over the remaining depreciable life of the underlying assets, except in certain jurisdictions where the commissions have approved a shorter refund period for certain assets not subject to IRS normalization rules.	No


Line Item	Description	End Date of Remaining Recovery/Refund Period	Return
Electric distribution formula rate annual reconciliations	Represents under/(over)-recoveries related to electric distribution service costs recoverable through ComEd's performance-based formula rate, which was updated annually with rates effective on January 1st.	2026	Yes
Electric distribution formula rate significant one-time events	Represents deferred distribution service costs related to ComEd's significant one-time events (e.g., storm costs), which are recovered over 5 years from date of the event.	2028	Yes
Electric energy costs	Under (over) recoveries related to energy related costs recoverable (refundable) under approved rate riders.	2025	No
Energy efficiency costs	Represents ComEd's costs recovered through the energy efficiency formula rate tariff and the reconciliation of the difference of the revenue requirement in effect for the prior year and the revenue requirement based on actual prior year costs. Deferred energy efficiency costs are recovered over the weighted average useful life of the related energy measure.	2036	Yes
MGP remediation costs	Represents environmental remediation costs for MGP sites.	Over the expected remediation period. See Note 12 - Commitments and Contingencies for additional information.	No
Multi-year plan reconciliations	Represents under-recoveries related to electric distribution multi-year plans.	2027	Yes

Renewable energy	Represents the change in fair value of ComEd‘s 20-year floating-to-fixed long-term renewable energy swap contracts.	2032	No
Renewable portfolio standard costs	Represents an overcollection of funds from both ComEd customers and alternative retail electricity suppliers to be spent on future renewable energy procurements.	$1,296 million to be determined in pending ICC annual reconciliation for the Renewable Energy Adjustment rider. $73 million to be determined based on the Long-Term Renewable Resources Procurement Plan developed by the Illinois Power Agency	No


Line Item	Description	End Date of Remaining Recovery/Refund Period	Return
Transmission formula rate annual reconciliations	Under (over)-recoveries related to transmission service costs recoverable through ComEd’s FERC formula rates, which are updated annually with rates effective each June 1st.	2026	Yes
Uncollectible accounts expense	Amounts represent the difference between annual uncollectible accounts loss expense and revenues collected in rates through ICC-approved riders. The difference between uncollectible accounts expense and revenues collected through rider each calendar year is recovered over a twelve-month period beginning in June of the following calendar year.	2025	No
Zero emission credit	Represents ZEC procurement costs and any reasonable costs ComEd has incurred to implement and comply with the ZEC procurement process.	Over 9 months starting with the September billing period and ending with the following May billing period.	No

Decommissioning the Regulatory Agreement Units

The regulatory agreements with the ICC dictates obligations related to the shortfall or excess of Nuclear Decommissioning Trust (NDT) funds necessary for decommissioning the former ComEd units on a unit-by-unit basis. Given no further recovery from customers is permitted and Constellation retains an obligation to ultimately return excess funds to ComEd customers (on a unit-by-unit basis), to the extent excess funds are expected for each unit, decommissioning-related activities prior to separation on February 1, 2022 were offset in the Statement of Income with an offsetting adjustment to regulatory liabilities and noncurrent receivable from Generation (which is reported within Miscellaneous deferred debits on the Balance Sheet). Following the separation, decommissioning-related activities result in an adjustment to other deferred debits and an equal adjustment to the regulatory liabilities at ComEd. However, given the asymmetric settlement provision that does not allow for continued recovery from ComEd customers in the event of a shortfall, recognition of a regulatory asset is not permissible.

Capitalized Ratemaking Amounts Not Recognized

As of December 31, 2024 and 2023, ComEd had $46 million and $32 million, respectively, of authorized amounts capitalized for ratemaking purposes related to earnings on shareholders' investment on its electric distribution rates and formula rates regulatory assets that are not recognized for financial reporting purposes on the Balance Sheets. These amounts will be recognized as revenues in the Statement of Income in the periods they are billable to customers.

3. Accounts Receivable

Accumulated Provision for Uncollectible Accounts

The following tables present the rollforward of Accumulated Provision for Uncollectible Accounts on Customer Accounts Receivable (Account 144).


	For the Year Ended December 31, 2024
Balance at December 31, 2023	$	69
Plus: Current period provision for uncollectible accounts(a)	78
Less: Write-offs, net of recoveries(b)	38
Balance at December 31, 2024	$	109


	For the Year Ended December 31, 2023
Balance at December 31, 2022	$	59
Plus: Current period provision for uncollectible accounts	53
Less: Write-offs, net of recoveries	43
Balance at December 31, 2023	$	69

__________

(a)The increase is primarily a result of increased aging of receivables.

(b)Recoveries were not material.

The following tables present the rollforward of Accumulated Provision for Uncollectible Accounts on Other Accounts Receivable (Account 144).


	For the Year Ended December 31, 2024
Balance at December 31, 2023	$	17
Plus: Current period provision for uncollectible accounts(a)	21
Less: Write-offs, net of recoveries(b)	4
Balance at December 31, 2024	$	34


	For the Year Ended December 31, 2023
Balance at December 31, 2022	$	17
Plus: Current period benefit for uncollectible accounts	5
Less: Write-offs, net of recoveries	5
Balance at December 31, 2023	$	17

__________

(a)The increase is primarily a result of increased aging of receivables.

(b)Recoveries were not material.

Accrued Utility Revenues

ComEd accrued $335 million and $351 million of unbilled customer revenues at December 31, 2024 and 2023, respectively, in Account 173, Accrued Utility Revenues.

Purchase of Customer and Other Accounts Receivable

ComEd is required under legislation and regulations in Illinois to purchase certain receivables from alternative retail electric suppliers that participate in its consolidated billing. The following table presents the total receivables ComEd purchased:


	For the Years Ended December 31,
	2024		2023
Total receivables ComEd purchased	$	964	$	942

4. Property, Plant, and Equipment

The following table presents the average service life for each asset category in number of years as of December 31, 2024:


Asset Category						Average Service Life (years)
Electric - transmission and distribution						3-80
Other property, plant and equipment						29-50

The following table presents the annual depreciation rates for each asset category:

Annual Depreciation Rates

December 31, 2024

December 31, 2023

Electric-transmission and distribution

3.11%

3.04%

Allowance for Funds Used During Construction (AFUDC)

The credits to AFUDC debt and equity were $75 million and $72 million for the years ended December 31, 2024 and 2023, respectively.

See Note 1 - Significant Accounting Policies for additional information regarding property, plant and equipment policies. See Note 10 - Debt and Credit Agreements for additional information regarding ComEd's property, plant and equipment subject to mortgage liens.

5. Asset Retirement Obligations

ComEd has AROs primarily associated with the abatement and disposal of equipment and buildings contaminated with asbestos and polychlorinated biphenyls. See Note 1 — Significant Accounting Policies for additional information on ComEd’s accounting policy for AROs.

The following table provides a rollforward of the AROs reflected on ComEd’s Balance Sheets from December 31, 2022 to December 31, 2024:


AROs at December 31, 2022 (Account 230)	$	150
Revisions in estimates of cash flows	(3)
Accretion expense(a)	6
Payments	(2)
AROs at December 31, 2023 (Account 230)	$	151
Revisions in estimates of cash flows	12
Accretion expense(a)	7
Payments	(1)
AROs at December 31, 2024 (Account 230)	$	169

__________

(a)The majority of the accretion is recorded as an increase to a regulatory asset (Account 182.3, Other Regulatory Assets) due to the associated regulatory treatment.

6. Intangible Assets

ComEd’s gross amount of goodwill, accumulated impairment losses, and carrying amount of goodwill were $4,608 million, $1,983 million, and $2,625 million, respectively, for both December 31, 2024 and 2023. There were no additions or impairments during the years ended December 31, 2024 and 2023. The gross amount reflects goodwill recorded in 2000 from the PECO/Unicom (predecessor parent company of ComEd).

Goodwill is recorded in Account 114, Electric Plant Acquisition Adjustments and Account 115, Accumulated Provision for Amortization of Electric Plant Acquisition Adjustments, as approved by FERC (Docket No. AC01-38-000). Goodwill is not amortized, but is subject to an assessment for impairment at least annually, or more frequently if events occur or circumstances change that would more likely than not reduce the fair value of the ComEd reporting unit below its carrying amount. A reporting unit is an operating segment or one level below an operating segment (known as a component) and is the level at which goodwill is assessed for impairment. A component of an operating segment is a reporting unit if the component

constitutes a business for which discrete financial information is available and its operating results are regularly reviewed by segment management. ComEd has a single operating segment. There is no level below this operating segment for which operating results are regularly reviewed by segment management. Therefore, ComEd’s operating segment is considered its only reporting unit for goodwill impairment assessment purposes.

Entities assessing goodwill for impairment have the option of first performing a qualitative assessment to determine whether a quantitative assessment is necessary. As part of the qualitative assessments, ComEd evaluates, among other things, management's best estimate of projected operating and capital cash flows for its businesses, outcomes of recent regulatory proceedings, changes in certain market conditions, including the discount rate and regulated utility peer EBITDA multiples, and the passing margin from its last quantitative assessment performed. If an entity bypasses the qualitative assessment, a quantitative, fair value-based assessment is performed, which compares the fair value of the reporting unit to its carrying amount, including goodwill. If the carrying amount of the reporting unit exceeds its fair value, the entity recognizes an impairment charge, which is limited to the amount of goodwill allocated to the reporting unit.

Application of the goodwill impairment assessment requires management judgment, including the identification of reporting units and determining the fair value of the reporting unit, which management estimates using a weighted combination of a discounted cash flow analysis and a market multiples analysis. Significant assumptions used in these fair value analyses include discount and growth rates, utility sector market performance and transactions, projected operating and capital cash flows for ComEd's business, and the fair value of debt.

2024 and 2023 Goodwill Impairment Assessment. ComEd qualitatively determined that it was more likely than not that the fair value of its reporting unit exceeded the carrying value and, therefore, did not perform quantitative assessments as of November 1, 2024 and 2023. On December 14, 2023, due to the issuance of the ICC's final order rejecting ComEd’s proposed Grid Plan and establishing retail rates for 2024-2027 as further discussed in Note 2 - Regulatory Matters, Exelon’s stock price decreased approximately 10% triggering an interim quantitative assessment for potential goodwill impairment at ComEd. ComEd performed a quantitative assessment as of December 31, 2023, comparing the estimated fair value of ComEd to its carrying value, and determined there was no indication of goodwill impairment

While the annual and interim assessments indicated no impairments, certain assumptions used to estimate reporting unit fair values are highly sensitive to changes. Adverse regulatory actions or changes in significant assumptions could potentially result in future impairment of ComEd's goodwill, which could be material.

7. Income Taxes

Components of Income Tax Expense or Benefit

Income tax expense (benefit) from continuing operations is comprised of the following components:


	For the Years Ended December 31,
	2024		2023
Included in operations:
Federal
Current	$	74	$	136
Deferred	(76)		39
Investment tax credit amortization	(1)		(1)
State
Current	59		(10)
Deferred	57		150
Total (Accounts 409.1, 409.2, 410.1, 411.1, 411.4)	$	113	$	314

The effective income tax rate from continuing operations varies from the U.S. Federal statutory rate principally due to the following:


	For the Years Ended December 31,
	2024		2023
U.S. Federal statutory rate	21.0	%	21.0	%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	7.8		7.8

Amortization of investment tax credit, including deferred taxes on basis difference	(0.1)		(0.1)
Plant basis differences	(0.7)		(0.4)
Production tax credits and other credits	(0.8)		(0.4)
Excess deferred tax amortization	(17.3)		(5.4)

Other	(0.3)		(0.2)
Effective income tax rate	9.6	%	22.3	%

The tax effects of temporary differences, which give rise to significant portions of the deferred tax assets and liabilities, as of December 31, 2024 and 2023 are presented below:


	2024		2023
Deferred tax liabilities, net:
Plant basis differences	$	(5,061)	$	(4,983)
Derivative financial instruments	36		37


Deferred pension and post-retirement obligation	(339)		(299)
Deferred debt refinancing costs	(4)		(5)
Regulatory	(515)		(405)
Corporate alternative minimum tax	47		118
Other, net	250		226
Deferred income tax liabilities, net (Accounts 190, 282 and 283)	$	(5,586)	$	(5,311)
Unamortized investment tax credits (Account 255)	(6)		(7)

Total deferred income tax liabilities, net and unamortized investment tax credits	$	(5,592)	$	(5,318)

The following table provides ComEd's carryforwards as of December 31, 2024:


	At December 31, 2024
Federal
Minimum tax credit carryforward(a)	$	47

__________

(a)The Corporate Alternative Minimum Tax credit carryfoward has an indefinite carryforward period.

Tabular reconciliation of unrecognized tax benefits

The following table provides a GAAP reconciliation of ComEd’s unrecognized tax benefits as of December 31, 2024 and 2023:


Unrecognized tax benefits at January 1, 2023	$	16
Changes to positions that only affect timing	(1)
Increases based on tax positions related to 2023	1
Decreases based on tax positions prior to 2023	(8)
Unrecognized tax benefits at December 31, 2023	$	8

Unrecognized tax benefits at January 1, 2024	$	8
Changes to positions that only affect timing	—
Increases based on tax positions related to 2024	2
Increases based on tax positions prior to 2024	1
Unrecognized tax benefits at December 31, 2024	$	11

Recognition of unrecognized tax benefits

As of December 31, 2024 and December 31, 2023, ComEd has $11 million and $6 million, respectively, of unrecognized tax benefits that, if recognized, would decrease the effective tax rate.

Reasonably possible the total amount of unrecognized tax benefits could significantly increase or decrease within 12 months after the reporting date

As of December 31, 2024, ComEd has no unrecognized tax benefits that could significantly decrease within the 12 months after the reporting date.

Total amounts of interest and penalties recognized

As of December 31, 2024 and December 31, 2023, ComEd has accrued interest of $2 million and $1 million, respectively, and no penalties related to income tax positions.

Description of tax years that remain subject to examination by major jurisdiction


			Open Years
Federal consolidated income tax returns			2010-2023
Illinois unitary corporate income tax returns			2012-2023

Other Tax Matters

Corporate Alternative Minimum Tax

On August 16, 2022, the IRA was signed into law and implemented a new corporate alternative minimum tax (CAMT) that imposes a 15% tax on modified GAAP net income. Corporations are entitled to a tax credit (minimum tax credit) to the extent the CAMT liability exceeds the regular tax liability. This amount can be carried forward indefinitely and used in future years when regular tax exceeds the CAMT.

Based on the existing statue, ComEd is subject to and reports CAMT on an independent basis in the Statement of Income and the Balance Sheets. The deferred tax asset related to the minimum tax credit carryforward will be realized to the extent ComEd’s consolidated deferred tax liabilities exceed the minimum tax credit carryforward. ComEd’s deferred tax liabilities are expected to exceed the minimum tax credit carryforward for the foreseeable future and thus no valuation allowance is required. ComEd is continuing to assess the financial statement impacts of the IRA and will update estimates based on future guidance issued by the U.S. Treasury.

On September 12, 2024, the U.S. Treasury issued proposed regulations providing further guidance addressing the implementation of CAMT. The proposed regulations are consistent with Exelon's prior interpretation and therefore there are no financial statement impacts. Exelon will continue to monitor and assess the potential financial statement impacts of final regulations or other guidance when issued.

Long-Term Marginal State Income Tax Rate

Quarterly, Exelon reviews and updates its marginal state income tax rates for changes in state apportionment. ComEd remeasures its existing deferred income tax balances to reflect the changes in marginal rates, which results in either an

increase or decrease to their net deferred income tax liability balances. ComEd records corresponding regulatory liabilities or assets to the extent such amounts are probable of settlement or recovery through customer rates and an adjustment to income tax expense for all other amounts. There were no adjustments to ComEd's deferred income tax liability balance for the years ended December 31, 2024 and 2023.

Allocation of Tax Benefits

ComEd is party to an agreement with Exelon and other subsidiaries of Exelon that provides for the allocation of consolidated tax liabilities and benefits (Tax Sharing Agreement). The Tax Sharing Agreement provides that each party is allocated an amount of tax similar to that which would be owed had the party been separately subject to tax. In addition, any net federal and state benefits attributable to Exelon is reallocated to ComEd and the other Registrants. That allocation is treated as a contribution to the capital of the party receiving the benefit.

ComEd recorded a federal tax benefit allocation from Exelon under the Tax Sharing Agreement as of December 31, 2024 and 2023 of $29 million and $12 million, respectively.

8. Retirement Benefits

Defined Benefit Pension and Other Postretirement Employee Benefits

The listing below shows the pension and OPEB plans in which ComEd employees participated as of December 31, 2024:

Name of Plan(a):

Qualified Pension Plans:

◦Exelon Corporation Retirement Program

◦Exelon Corporation Pension Plan for Bargaining Unit Employees

◦Exelon Pension Plan

◦Pepco Holdings LLC Retirement Plan

Non-Qualified Pension Plans:

◦Exelon Corporation Supplemental Pension Benefit Plan and 2000 Excess Benefit Plan

◦Exelon Corporation Supplemental Management Retirement Plan

OPEB Plans:

◦PECO Energy Company Retiree Medical Plan

◦Exelon Corporation Health Care Program

◦Pepco Holdings LLC Welfare Plan for Retirees

◦Exelon Corporation Employees' Life Insurance Plan

◦Exelon Corporation Health Reimbursement Arrangement Plan

◦BGE Retiree Medical Plan

◦Exelon Retiree Medical Plan of Constellation Energy Nuclear Group, LLC

◦Exelon Retiree Dental Plan of Constellation Energy Nuclear Group, LLC

__________

(a)Employees generally remain in their legacy benefit plans when transferring between operating companies.

Cost Allocation to ComEd

ComEd accounts for its participation in Exelon’s pension and OPEB plans by applying multi-employer accounting. Components of pension and OPEB costs and contributions have been, and will continue to be, allocated to ComEd based on both active and retired employee participation in each plan.

The amounts below represent ComEd's allocated portion of the pension and OPEB plan costs, which were included in Operating expenses (Account 401) within ComEd's Statement of Income and Utility Plant (Account 101-106, 114) within ComEd's Balance Sheets for the years ended December 31, 2024 and 2023:


	2024		2023
Pension and OPEB	$	72	$	26

Contributions

The following table provides ComEd's contributions to the pension and OPEB plans for the years ended December 31, 2024 and 2023:


	2024		2023
Pension benefits	$	7	$	24
OPEB	18		17

Management considers various factors when making pension funding decisions, including actuarially determined minimum contribution requirements under the Employee Retirement Income Security Act of 1974, as amended, contributions required to avoid benefit restrictions and at-risk status as defined by the Pension Protection Act of 2006 (the Act), management of the pension obligation and regulatory implications. The Act requires the attainment of certain funding levels to avoid benefit restrictions (such as an inability to pay lump sums or to accrue benefits prospectively), and at-risk status (which triggers higher minimum contribution requirements and participant notification). The projected contributions below reflect a funding strategy to make annual contributions with the objective of achieving 100% funded status on an accumulated benefit obligation basis over time. This funding strategy helps minimize volatility of future period required pension contributions. Unlike the qualified pension plans, Exelon’s non-qualified pension plans are not funded, given that they are not subject to statutory minimum contribution requirements.

While OPEB plans are also not subject to statutory minimum contribution requirements, Exelon does fund certain of its plans. For Exelon's funded OPEB plans, contributions generally equal accounting costs, however, Exelon’s management has historically considered several factors in determining the level of contributions to its OPEB plans, including liabilities management, levels of benefit claims paid, and regulatory implications (amounts deemed prudent to meet regulatory expectations and best assure continued rate recovery). The amounts below include benefit payments related to unfunded plans.

The following table provides ComEd's planned contributions to the qualified pension plans, planned benefit payments to non-qualified pension plans, and planned contributions to OPEB plans in 2025:


	Qualified Pension Plans		Non-Qualified Pension Plans		OPEB
Planned contributions	$	187	$	2	$	21

Defined Contribution Savings Plan

ComEd participates in a 401(k) defined contribution savings plans that is sponsored by Exelon. The plan is qualified under applicable sections of the Internal Revenue Code and allow employees to contribute a portion of their pre-tax and/or after-tax income in accordance with specified guidelines. ComEd matches a percentage of the employee contributions up to certain limits. The following table presents the employer contributions and employer matching contributions to the savings plan during the years ended December 31, 2024 and 2023:


	2024		2023
Savings plan matching contributions	$	46	$	47

9. Derivative Financial Instruments

ComEd uses derivative instruments to manage commodity price risk related to ongoing business operations. ComEd does not execute derivatives for speculative or proprietary trading purposes.

Authoritative guidance requires that derivative instruments be recognized as either assets or liabilities at fair value, with changes in fair value of the derivative recognized in earnings immediately. Other accounting treatments are available through special election and designation, provided they meet specific, restrictive criteria both at the time of designation and on an ongoing basis. These alternative permissible accounting treatments include Normal Purchase Normal Sale (NPNS), cash flow hedges, and fair value hedges. At ComEd, derivative economic hedges related to commodities are recorded at fair value and offset by a corresponding regulatory asset or liability. For all NPNS derivative instruments, accounts receivable or accounts payable are recorded when derivatives settle and revenue or expense is recognized in earnings as the underlying physical commodity is sold or consumed.

ComEd’s use of cash collateral is generally unrestricted unless ComEd is downgraded below investment grade.

Commodity Price Risk

ComEd employs established policies and procedures to manage its risk associated with market fluctuations in commodity prices by entering into physical and financial derivative contracts, which are either determined to be non-derivative or classified as economic hedges.

ComEd procures electric supply through a competitive procurement process approved by the ICC. ComEd’s hedging programs are intended to reduce exposure to energy price volatility and have no direct earnings impact as the costs are fully recovered from customers through regulatory-approved recovery mechanisms. The following table provides a summary of ComEd's primary derivative hedging instruments, listed by commodity and accounting treatment.


Commodity	Accounting Treatment	Hedging Instrument
Electricity	NPNS	Fixed price contracts based on all requirements in the IPA procurement plans.
Electricity	Changes in fair value of economic hedge recorded to an offsetting regulatory asset or liability(a)	20-year floating-to-fixed energy swap contracts beginning June 2012 based on the renewable energy resource procurement requirements in the Illinois Settlement Legislation of approximately 1.3 million MWhs per year.

__________

(a)See Note 2 - Regulatory Matters for additional information.

The following table provides a summary of the derivative fair value balances recorded by ComEd as of December 31, 2024 and 2023:


	December 31, 2024		December 31, 2023
Mark-to-market derivative liabilities - current (Account 242)	$	(29)	$	(27)
Mark-to-market derivative liabilities - noncurrent (Account 253)	(103)		(106)
Total mark-to-market derivative liabilities	$	(132)	$	(133)

Credit Risk

ComEd would be exposed to credit-related losses in the event of non-performance by counterparties on executed derivative instruments. The credit exposure of derivative contracts, before collateral, is represented by the fair value of contracts at the reporting date.

ComEd has contracts to procure electric supply that provide suppliers with a certain amount of unsecured credit. If the exposure on the supply contract exceeds the amount of unsecured credit, the suppliers may be required to post collateral. The net credit exposure is mitigated primarily by the ability to recover procurement costs through customer rates. As of December 31, 2024 and 2023, the amount of cash collateral held from external counterparties was $176 million and $146 million, respectively, which is recorded in Miscellaneous Current and Accrued Liabilities in the Balance Sheets (Account 242). The amount of cash collateral received from external counterparties remained relatively consistent as of December 31, 2024 due to stable energy prices.

ComEd's electric supply procurement contracts do not contain provisions that would require them to post collateral.

10. Debt and Credit Agreements

Short-Term Borrowings

ComEd meets its short-term liquidity requirements primarily through the issuance of commercial paper. ComEd may use its credit facilities for general corporate purposes, including meeting short-term funding requirements and the issuance of letters of credit.

Commercial Paper

The following table reflects ComEd's commercial paper program supported by the revolving credit agreements as of December 31, 2024 and 2023:


Credit Facility Size at December 31,				Outstanding Commercial Paper at December 31,				Average Interest Rate on Commercial Paper Borrowings at December 31,
2024(a)		2023(a)		2024		2023		2024		2023
$	1,000	$	1,000	$	36	$	202	4.55	%	5.53	%

__________

(a)Excludes credit facility agreements arranged at minority and community banks. See below for additional information.

In order to maintain its commercial paper program in the amounts indicated above, ComEd must have credit facilities in place, at least equal to the amount of its commercial paper program. ComEd does not issue commercial paper in an aggregate amount exceeding the then available capacity under its credit facility.

As of December 31, 2024, ComEd had the following aggregate bank commitments, credit facility borrowings, and available capacity under its credit facility:


							Available Capacity at December 31, 2024
Facility Type	Aggregate Bank Commitment(a)		Facility Draws		Outstanding Letters of Credit		Actual		To Support Additional Commercial Paper
Syndicated Revolver	$	1,000	$	—	$	15	$	985	$	949

__________

(a)Excludes credit facility agreements arranged at minority and community banks. See below for additional information.

The following table reflects ComEd's credit facility agreements arranged at minority and community banks as of December 31, 2024 and 2023. These are excluded from the Maximum Program Size and Aggregate Bank Commitment amounts within the two tables above and the facilities may be used to issue letters of credit.


Aggregate Bank Commitments				Outstanding Letters of Credit
2024(a)		2023		2024		2023
$	40	$	40	$	3	$	7

__________

(a)These facilities were entered into on October 4, 2024 and expire October 3, 2025.

Revolving Credit Agreements

On August 29, 2024, ComEd amended and restated its syndicated revolving credit facility, extending the maturity date to August 29, 2029. The credit agreements have an aggregate bank commitment of $1 billion and an interest rate of Secured Overnight Financing Rate (SOFR) plus 1.00%.

Borrowings under ComEd’s revolving credit agreements bear interest at a rate based upon either the prime rate or a SOFR-based rate, plus an adder based upon ComEd’s credit rating. ComEd has an adder of 0 basis points and 100 basis points for prime based and SOFR-based borrowings, respectively. If ComEd loses its investment grade rating, the maximum adders for prime rate borrowings and SOFR-based rate borrowings would be 65 basis points and 165 basis points, respectively. The credit agreements also require ComEd to pay a facility fee based upon the aggregate commitments. The fee varies depending upon the credit rating of ComEd. ComEd had no outstanding amounts on the revolving credit facility as of December 31, 2024.

Short-Term Loan Agreements

On May 9, 2023, ComEd entered into a 364-day term loan agreement for $400 million with a variable rate equal to SOFR plus 1.00% and an expiration date of May 7, 2024. On May 1, 2024, ComEd entered into an agreement to extend the loan through the expiration date of June 28, 2024. The original proceeds from the loan were used to repay outstanding commercial paper obligations and for general corporate purposes. The balance of the loan was repaid on May 16, 2024. Refer to the Issuance of Long-Term Debt table below for further information.

Long-Term Debt

The following table presents the outstanding long-term debt at ComEd as of December 31, 2024 and 2023:


			December 31,
	Rates	Maturity Date	2024		2023
Long-term debt
First Mortgage Bonds:
Fixed rates (Account 221)(a)	2.20 - 6.45%	2026 - 2054	$	12,154	$	11,603
Finance Leases (Accounts 227 and 243)	7.49%	2053	7		8
Total long-term debt			$	12,161	$	11,611
Unamortized debt discount and premium, net (Account 225 and 226)			(31)		(28)
Long-term debt			$	12,130	$	11,583

Long-term debt to financing trusts(b)
Subordinated debentures to ComEd Financing III (Account 223)	6.35%	2033	$	206	$	206

__________

(a)Substantially all of ComEd’s assets, other than expressly excepted property, are subject to the lien of its mortgage indenture.

(b)Amount owed to this financing trust is recorded as Long-term debt to financing trust within ComEd's Balance Sheets.

ComEd issued the following long-term debt on May 13, 2024:

Type

Interest
Rate

Maturity

Amount

Use of Proceeds

First Mortgage Bonds Series 136

5.30

June 1, 2034

400

Repay existing indebtedness, repay outstanding commercial paper obligations, and to fund other general corporate purposes.

First Mortgage Bonds Series 137

5.65

June 1, 2054

400

Repay existing indebtedness, repay outstanding commercial paper obligations, and to fund other general corporate purposes.

Long-term debt maturities at ComEd in the periods 2025 through 2029 and thereafter are as follows:


Year
2025	$	—
2026	500
2027	350
2028	550
2029	—
Thereafter	10,968		(a)
Total	$	12,368

________

(a)Includes $206 million due to ComEd financing trust.

Debt Covenants

As of December 31, 2024, ComEd is in compliance with its debt covenants.

11. Fair Value of Financial Assets and Liabilities

ComEd measures and classifies fair value measurements in accordance with the hierarchy as defined by authoritative guidance. The hierarchy prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:

•Level 1 — quoted prices (unadjusted) in active markets for identical assets or liabilities that ComEd has the ability to liquidate as of the reporting date.

•Level 2 — inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.

•Level 3 — unobservable inputs, such as internally developed pricing models or third-party valuations for the asset or liability due to little or no market activity for the asset or liability.

Fair Value of Financial Liabilities Recorded at Amortized Cost

The following table presents the carrying amounts and fair values of ComEd's short-term liabilities, long-term debt, and trust preferred securities (long-term debt to financing trusts) as of December 31, 2024 and 2023. ComEd has no financial liabilities classified as Level 1 or measured using the NAV practical expedient.

The carrying amounts of ComEd's short-term liabilities as presented on ComEd's Balance Sheets are representative of their fair value (Level 2) because of the short-term nature of these instruments.


	December 31, 2024										December 31, 2023
	Carrying Amount		Fair Value								Carrying Amount		Fair Value
			Level 1		Level 2		Level 3		Total				Level 1		Level 2		Level 3		Total

Long-term debt (Accounts 221, 224-227)(a)	$	12,130	$	—	$	10,260	$	—	$	10,260	$	11,583	$	—	$	10,210	$	—	$	10,210
Long-term debt to financing trust (Account 223)	206		—		—		208		208		206		—		—		208		208

_________

(a)Includes unamortized debt discount and premium, net, and finance lease liabilities which are not fair valued. Refer to Note 10 - Debt and Credit Agreements.

ComEd uses the following methods and assumptions to estimate fair value of financial liabilities recorded at carrying cost:


Type	Level	Valuation
Long-Term Debt, including amounts due within one year
Taxable Debt Securities	2	The fair value is determined by a valuation model that is based on a conventional discounted cash flow methodology and utilizes assumptions of current market pricing curves. ComEd obtains credit spreads based on trades of existing ComEd debt securities as well as other issuers in the utility sector with similar credit ratings. The yields are then converted into discount rates of various tenors that are used for discounting the respective cash flows of the same tenor for each bond or note.
Long-Term Debt to Financing Trusts
Long-Term Debt to Financing Trusts	3	Fair value is based on publicly traded securities issued by the financing trusts. Due to low trading volume of these securities and qualitative factors, such as market conditions, investor demand, and circumstances related to each issue, this debt is classified as Level 3.

Recurring Fair Value Measurements

The following table presents assets and liabilities measured and recorded at fair value on ComEd’s Balance Sheets on a recurring basis and their level within the fair value hierarchy as of December 31, 2024 and 2023. ComEd has no financial assets or liabilities measured using the NAV practical expedient:


At December 31, 2024	Level 1		Level 2		Level 3		Total
Assets
Cash equivalents (Accounts 132-134, 136, and 186)(a)	$	390	$	—	$	—	$	390

Total assets	390		—		—		390
Liabilities
Deferred compensation obligation (Accounts 228.3, 242)	—		(8)		—		(8)
Commodity derivative liabilities(b) (Accounts 242, 253)	—		—		(132)		(132)
Total liabilities	—		(8)		(132)		(140)
Total net assets (liabilities)	$	390	$	(8)	$	(132)	$	250

At December 31, 2023	Level 1		Level 2		Level 3		Total
Assets
Cash equivalents (Accounts 132-134, 136, and 186)(a)	$	453	$	—	$	—	$	453

Total assets	453		—		—		453
Liabilities
Deferred compensation obligation (Accounts 228.3, 242)	—		(8)		—		(8)
Commodity derivative liabilities(b) (Accounts 242, 253)	—		—		(133)		(133)
Total liabilities	—		(8)		(133)		(141)
Total net assets (liabilities)	$	453	$	(8)	$	(133)	$	312

__________

(a)ComEd excludes cash of $17 million and $46 million as of December 31, 2024 and 2023, respectively, and restricted cash of $176 million and $147 million as of December 31, 2024 and 2023, respectively, and includes long-term restricted cash of $41 million and $174 million as of December 31, 2024 and 2023, respectively, which is reported in Other deferred debits in the Balance Sheets.

(b)The Level 3 balance consists of the current and noncurrent liability of $29 million and $103 million, respectively, as of December 31, 2024, and $27 million and $106 million, respectively, as of December 31, 2023 related to floating-to-fixed energy swap contracts with unaffiliated suppliers.

Reconciliation of Level 3 Assets and Liabilities

The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis during the years ended December 31, 2024 and 2023:


	Commodity Derivatives
Balance at December 31, 2023	$	(133)
Total realized / unrealized gains (losses) included in regulatory assets/liabilities(a)	1
Balance at December 31, 2024 (Accounts 242, 253)	$	(132)	(b)


	Commodity Derivatives
Balance at December 31, 2022	$	(84)
Total realized / unrealized gains (losses) included in regulatory assets/liabilities(a)	(49)
Balance at December 31, 2023 (Accounts 242, 253)	$	(133)

__________

(a)Includes $40 million of decreases in fair value and an increase for realized gains due to settlements of $40 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the year ended December 31, 2024. Includes $83 million of decreases in fair value and an increase for realized gains due to settlements of $34 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the year ended December 31, 2023.

(b)The balance consists of a current (Account 242) and noncurrent (Account 253) liability of $29 million and $103 million, respectively, as of December 31, 2024.

Valuation Techniques Used to Determine Fair Value

Cash Equivalents. Investments with original maturities of three months or less when purchased, including mutual and money market funds, are considered cash equivalents. The fair values are based on observable market prices and, therefore, are included in the recurring fair value measurements hierarchy as Level 1.

Deferred Compensation Obligations. ComEd’s deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. ComEd includes such plans in other current and noncurrent liabilities in its Balance Sheets. The value of ComEd’s deferred compensation obligations is based on the market value of the participants’ notional investment accounts. The underlying notional investments are comprised primarily of equities, mutual funds,

commingled funds, and fixed income securities, which are based on directly and indirectly observable market prices. Since the deferred compensation obligations themselves are not exchanged in an active market, they are categorized as Level 2 in the fair value hierarchy.

The value of certain employment agreement obligations (which are included with the Deferred Compensation Obligation in the tables above) are based on a known and certain stream of payments to be made over time and are categorized as Level 2 within the fair value hierarchy.

Commodity Derivatives. On December 17, 2010, ComEd entered into several 20-year floating to fixed energy swap contracts with unaffiliated suppliers for the procurement of long-term renewable energy and associated RECs. Delivery under the contracts began in June 2012. The fair value of these swaps has been designated as a Level 3 valuation due to the long tenure of the positions and the internal modeling assumptions. The modeling assumptions include using forward power prices. See Note 9 — Derivative Financial Instruments for additional information on mark-to-market derivatives. .

The following table discloses the significant unobservable inputs to the forward curve used to value mark-to-market derivatives:


Type of trade	Fair Value at December 31, 2024		Valuation Technique	Unobservable Input	2024 Range & Arithmetic Average
Commodity derivatives	$	(132)	Discounted Cash Flow	Forward power price(a)	$30.31	—	$59.88	$42.08

Type of trade	Fair Value at December 31, 2023		Valuation Technique	Unobservable Input	2023 Range & Arithmetic Average
Commodity derivatives	$	(133)	Discounted Cash Flow	Forward power price(a)	$30.27	—	$73.71	$43.35

__________

(a)An increase to the forward power price would increase the fair value.

12. Commitments and Contingencies

Commercial Commitments

ComEd's commercial commitments at December 31, 2024, representing commitments potentially triggered by future events, were as follows:


	Expiration within
	Total		2025		2026		2027		2028		2029		2030 and beyond
Letters of credit(a)	$	18	$	16	$	2	$	—	$	—	$	—	$	—
Surety bonds(b)	36		34		—		2		—		—		—
Financing trust guarantees(c)	200		—		—		—		—		—		200
Total commercial commitments	$	254	$	50	$	2	$	2	$	—	$	—	$	200

__________

(a)ComEd maintains non-debt letters of credit to provide credit support for certain transactions as requested by third parties.

(b)Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. Historically, payments under the guarantees have not been made and the likelihood of payments being required is remote.

(c)Reflects guarantee of ComEd securities held by ComEd Financing III.

Environmental Remediation Matters

General. ComEd’s operations have in the past, and may in the future, require substantial expenditures to comply with environmental laws. Additionally, under federal and state environmental laws, ComEd is generally liable for the costs of remediating environmental contamination of property now or formerly owned by them and of property contaminated by hazardous substances generated by them. ComEd owns or leases a number of real estate parcels, including parcels on which its operations or the operations of others may have resulted in contamination by substances that are considered hazardous under environmental laws. In addition, ComEd is currently involved in a number of proceedings relating to sites where hazardous substances have been deposited and may be subject to additional proceedings in the future. Unless otherwise disclosed, ComEd cannot reasonably estimate whether it will incur significant liabilities for additional investigation and remediation costs at these or additional sites identified by ComEd, environmental agencies or others, or whether such costs

will be recoverable from third parties, including customers. Additional costs could have a material, unfavorable impact on ComEd's financial statements.

Manufactured Gas Plant (MGP) Sites. ComEd has identified sites where former MGP activities have or may have resulted in actual site contamination. For some sites, there are additional potentially responsible parties that may share responsibility for the ultimate remediation of each location.

ComEd has 16 sites currently under some degree of active study and/or remediation. ComEd expects the majority of the remediation at these sites to continue through at least 2031.

The historical nature of the MGP sites, and the fact that many of the sites have been buried and built over, impacts the ability to determine a precise estimate of the ultimate costs prior to initial sampling and determination of the exact scope and method of remedial activity. Management determines its best estimate of remediation costs using all available information at the time of each study, including probabilistic and deterministic modeling, and the remediation standards currently required by the applicable state environmental agency. Prior to completion of any significant clean up, each site remediation plan is approved by the appropriate state environmental agency.

ComEd, pursuant to an ICC order, is currently recovering environmental remediation costs of former MGP facility sites through customer rates.

In 2024, ComEd completed an annual study of its future estimated MGP remediation requirements. The study resulted in an increase of $13 million to the environmental liability and related Regulatory asset. The increase was primarily due to increased costs resulting from inflation and changes in remediation plans.

At December 31, 2024 and 2023, ComEd had accrued the following undiscounted amounts for environmental liabilities in Account 228.4, Accumulated Miscellaneous Operating Provisions, in its Balance Sheets:


	December 31, 2024		December 31, 2023
Total environmental investigation and remediation liabilities	$	285	$	303
Portion of total related to MGP investigation and remediation	284		302

Litigation and Regulatory Matters

Fund Transfer Restrictions. Under applicable law, ComEd can pay dividends only from retained, undistributed or current earnings. A significant loss recorded at ComEd may limit the dividends that it can distribute to Exelon.

ComEd has agreed in connection with financings arranged through ComEd Financing III that it will not declare dividends on any shares of its capital stock in the event that: (1) it exercises its right to extend the interest payment periods on the subordinated debt securities issued to ComEd Financing III; (2) it defaults on its guarantee of the payment of distributions on the preferred trust securities of ComEd Financing III; or (3) an event of default occurs under the Indenture under which the subordinated debt securities are issued. No such event has occurred.

Deferred Prosecution Agreement (DPA) and Related Matters. Exelon and ComEd received a grand jury subpoena in the second quarter of 2019 from the United States Attorney's Office for the Northern District of Illinois (USAO) requiring production of information concerning their lobbying activities in the State of Illinois. On October 4, 2019, Exelon and ComEd received a second grand jury subpoena from the USAO requiring production of records of any communications with certain individuals and entities. On October 22, 2019, the SEC notified Exelon and ComEd that it had also opened an investigation into their lobbying activities. On July 17, 2020, ComEd entered into a DPA with the USAO to resolve the USAO investigation, which included a payment to the U.S. Treasury of $200 million, which was paid in November 2020. The three-year term of the DPA ended on July 17, 2023, and on that same date the court granted the USAO’s motion to dismiss the pending charge against ComEd that had been deferred by the DPA.

On September 28, 2023, Exelon and ComEd reached a settlement with the Securities and Exchange Commission (SEC), concluding and resolving in its entirety the SEC investigation, which related to the conduct identified in the DPA that was entered into by ComEd in July 2020 and successfully exited in July 2023. Under the terms of the settlement, Exelon agreed to pay a civil penalty of $46.2 million and Exelon and ComEd agreed to cease and desist from committing or causing any violations and any future violations of specified provisions of the federal securities laws and rules promulgated thereunder. Exelon recorded an expense and paid the full amount of the penalty in 2023, which was reflected in Operating and maintenance expense within Exelon's Consolidated Statements of Operations and Comprehensive Income.

Subsequent to Exelon announcing the receipt of the USAO subpoenas, various lawsuits were filed, and various demand letters were received, related to the subject of the subpoenas, the conduct described in the DPA and the SEC's investigation, including:

•Four putative class action lawsuits against ComEd and Exelon were filed in federal court on behalf of ComEd customers in the third quarter of 2020 alleging, among other things, civil violations of federal racketeering laws. The court granted ComEd and Exelon's motion to dismiss these actions in 2021 and that dismissal was affirmed on appeal in 2022. Plaintiffs have no further appeal rights and therefore the dismissal is final.

•Three putative class action lawsuits against ComEd and Exelon were filed in Illinois state court in the third quarter of 2020 seeking restitution and compensatory damages on behalf of ComEd customers. The cases were consolidated into a single action in October of 2020. In 2021, the plaintiffs that filed the class action lawsuits in federal court ("federal plaintiffs") refiled their dismissed state law claims in state court. ComEd and Exelon moved to dismiss both lawsuits. The court dismissed the original consolidated state court lawsuit in December 2021 and dismissed the federal plaintiffs' refiled claims in February 2022. Both sets of plaintiffs appealed their dismissals, and the appeals were consolidated in March 2022. On September 8, 2023, the appellate court, affirmed the dismissals. On December 22, 2023, plaintiffs collectively filed a petition for leave to appeal to the Illinois Supreme Court, which ComEd and Exelon responded to on January 12, 2024. On March 27, 2024, the Illinois Supreme Court denied plaintiff's petition for leave to appeal. The dismissal of this action is final.

•On November 3, 2022, a plaintiff filed a putative class action complaint in Lake County, Illinois Circuit Court against ComEd and Exelon for unjust enrichment and deceptive business practices in connection with the conduct giving rise to the DPA. Plaintiff seeks an accounting and disgorgement of any benefits ComEd allegedly obtained from said conduct. ComEd and Exelon filed a motion to dismiss the Complaint on February 3, 2023. On June 16, 2023, the court granted ComEd and Exelon's motion to dismiss the action with prejudice. Plaintiff filed its notice of appeal of that dismissal on July 17, 2023. On April 12, 2024, the appellate court issued its decision affirming dismissal of the action. On June 3, 2024, plaintiff filed a petition for leave to appeal the dismissal to the Illinois Supreme Court, which is discretionary appeal. ComEd and Exelon filed its response to that petition on July 19, 2024. On September 25, 2024, the Illinois Supreme Court denied plaintiff's petition for leave to appeal. The dismissal of this action is now final.

•A putative class action lawsuit against Exelon and certain officers of Exelon and ComEd was filed in federal court in December 2019 alleging misrepresentations and omissions in Exelon’s SEC filings related to ComEd’s lobbying activities and the related investigations. The complaint was amended on September 16, 2020, to dismiss two of the original defendants and add other defendants, including ComEd. Defendants filed a motion to dismiss in November 2020. The court denied the motion in April 2021. Following mediation, the parties reached a settlement of the lawsuit, under which defendants agreed to pay plaintiffs $173 million. On May 26, 2023, plaintiffs filed a motion for preliminary approval of the settlement, which the court granted on June 9, 2023. The court granted final settlement approval on September 7, 2023. The settlement was fully covered by insurance and has been paid in full.

•Several shareholders have sent letters to the Exelon Board of Directors since 2020 demanding, among other things, that the Exelon Board of Directors investigate and address alleged breaches of fiduciary duties and other alleged violations by Exelon and ComEd officers and directors related to the conduct described in the DPA. In the first quarter of 2021, the Exelon Board of Directors appointed a Special Litigation Committee (SLC) consisting of disinterested and independent parties to investigate and address these shareholders' allegations and make recommendations to the Exelon Board of Directors based on the outcome of the SLC's investigation. In July 2021, one of the demand letter shareholders filed a derivative action against current and former Exelon and ComEd officers and directors, and against Exelon, as nominal defendant, asserting the same claims made in its demand letter. Since that date, multiple parties have filed separate derivative lawsuits that were subsequently consolidated. On October 12, 2021, the parties filed an agreed motion to stay the litigation for 120 days in order to allow the SLC to continue its investigation, which the court granted. The stay was extended several times. Through mediation efforts, a settlement of the derivative claims was reached by the SLC, the Independent Review Committee of the Board (which had been formed in the third quarter of 2022, to ensure the Board’s consideration of any SLC recommendations would be independent and objective), the Board, and certain of the derivative shareholders. On June 16, 2023, the SLC filed a motion for preliminary approval of the settlement, attaching the Stipulation and Agreement of Settlement (Stipulation), which contained the terms of the proposed settlement. The proposed settlement terms include but are not limited to: a payment of $40 million to Exelon by Exelon’s insurers of which $10 million constitutes the attorneys’ fee award to be paid to the Settling Shareholders’ counsel; various compliance and disclosure-related reforms; and certain changes in Board and Committee composition. On June 30, 2023, the court granted the non-settling shareholders’ request for limited discovery into the settlement. Following that discovery, on October 26, 2023, the SLC filed its renewed motion for preliminary approval with supporting submissions filed by the Independent Review Committee, Exelon, and the Settling Shareholders on that same day. The parties briefing on preliminary approval was completed on January 18,

2024. On September 20, 2024, the court denied without prejudice the SLC’s motion for preliminary approval. The court’s order provides that if the SLC can substantiate or otherwise revise the attorneys’ fees aspect of the settlement, then the SLC can renew its motion for preliminary approval by October 21, 2024. Otherwise, the court directed the parties to file a joint status report by October 30, 2024, proposing next steps to advance the case. On October 21, 2024, the SLC filed its second renewed motion for preliminary approval, and the Settling Shareholders filed a brief in support of the SLC's second renewed motion for preliminary approval. On November 20, 2024, the non-settling plaintiffs filed an opposition to the renewed motion for preliminary approval. On December 18, 2024, the SLC and Settling Shareholders filed replies in support of the renewed motion for preliminary approval.

In August 2022, the ICC concluded its investigation initiated on August 12, 2021 into rate impacts of conduct admitted in the DPA, including the costs recovered from customers related to the DPA and Exelon's funding of the fine paid by ComEd. On August 17, 2022, the ICC issued its final order accepting ComEd's voluntary customer refund offer of approximately $38 million (of which about $31 million was ICC jurisdictional; the remaining balance was FERC jurisdictional) that resolved the question of whether customer funds were used for DPA related activities. The customer refund included the cost of every individual or entity that was either (i) identified in the DPA or (ii) identified by ComEd as an associate of the former Speaker of the Illinois House of Representatives in the ICC proceeding. The ICC’s DPA investigation is now closed. The ICC jurisdictional refund was made to customers during the April 2023 billing cycle, as required by the ICC. The FERC jurisdictional refund was completed as of May 2024 as part of ComEd's transmission formula rate updated proceeding, submitted on May 12, 2023. The customer refund was not recovered in rates or charged to customers and ComEd will not seek or accept reimbursement or indemnification from any source other than Exelon.

General. ComEd is involved in various other litigation matters that are being defended and handled in the ordinary course of business. ComEd is also from time to time subject to audits and investigations by the FERC and other regulators. The assessment of whether a loss is probable or reasonably possible, and whether the loss or a range of loss is estimable, often involves a series of complex judgments about future events. ComEd maintains accruals for such losses that are probable of being incurred and subject to reasonable estimation. Management is sometimes unable to estimate an amount or range of reasonably possible loss, particularly where (1) the damages sought are indeterminate, (2) the proceedings are in the early stages, or (3) the matters involve novel or unsettled legal theories. In such cases, there is considerable uncertainty regarding the timing or ultimate resolution of such matters, including a possible eventual loss.

13. Shareholders' Equity

Common Stock Warrants (Account 201)

The following table presents warrants outstanding to purchase ComEd common stock and shares of common stock reserved for the conversion of warrants. The warrants entitle the holders to convert such warrants into common stock of ComEd at a conversion rate of one share of common stock for three warrants.


	December 31,
	2024	2023
Warrants outstanding	59,970	60,032
Common stock reserved for conversion	19,990	20,011

Preferred and Preference Securities (Account 204)

The following table presents ComEd's shares of preferred securities authorized, none of which were outstanding, as of December 31, 2024 and 2023:


			Preferred Securities Authorized
ComEd's shares			850,000

The following table presents ComEd's preference securities authorized, none of which were outstanding as of December 31, 2024 and 2023:


			Preference Securities Authorized
ComEd			6,810,451

14. Supplemental Financial Information

Supplemental Statement of Income Information

The following table provides additional information about material items recorded in ComEd's Statement of Income:


	For the Years Ended December 31,
	2024		2023
Taxes other than income (Accounts 408.1 and 408.2)
Utility(a)	$	300	$	299
Property	32		33
Payroll	37		31

________

(a)ComEd’s utility taxes represent municipal and state utility taxes and gross receipts taxes related to its operating revenues. The offsetting collection of utility taxes from customers is recorded in revenues in ComEd's Statement of Income.

Supplemental Statement of Cash Flows Information

The following tables provide additional information about material items recorded in ComEd's Statement of Cash Flows:


	For the Years Ended December 31,
	2024		2023
Cash paid during the year
Interest (net of amount capitalized)	$	485	$	441
Income taxes (net of refunds)	250		11

Non-cash investing activities
Decrease in capital expenditures not paid	$	(17)	$	(10)

15. Related Party Transactions

Service Company Costs for Corporate Support

ComEd receives a variety of corporate support services from Exelon's Business Services Corporation (BSC). The following table presents the service company costs allocated to ComEd:


	Operating and maintenance from affiliate				Capitalized costs
	For the Years Ended December 31,				For the Years Ended December 31,
	2024		2023		2024		2023
BSC	$	418	$	353	$	254	$	307

Current Payables to affiliates

The following table presents ComEd's current payables to affiliates:


	At December 31,
	2024		2023



BSC	$	67	$	64
ComEd Financing III	4		4

ComEd of Indiana	1		1




Other	5		4
Total (Account 234)	$	77	$	73

Noncurrent Receivables from affiliates

The following table presents ComEd's noncurrent receivables from affiliates:


	At December 31,
	2024		2023


Other	$	4	$	3
Total (Account 186)	$	4	$	3

Long-term debt to financing trusts

The following table presents ComEd's Long-term debt to financing trusts:


	At December 31,
	2024		2023
ComEd Financing III	$	206	$	205

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote. Report data on a year-to-date basis.
Line No.	Item (a)	Unrealized Gains and Losses on Available-For-Sale Securities (b)	Minimum Pension Liability Adjustment (net amount) (c)	Foreign Currency Hedges (d)	Other Adjustments (e)	Other Cash Flow Hedges Interest Rate Swaps (f)	Other Cash Flow Hedges [Specify] (g)	Totals for each category of items recorded in Account 219 (h)	Net Income (Carried Forward from Page 116, Line 78) (i)	Total Comprehensive Income (j)
1	Balance of Account 219 at Beginning of Preceding Year
2	Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3	Preceding Quarter/Year to Date Changes in Fair Value
4	Total (lines 2 and 3)								1,094,078,343	1,094,078,343
5	Balance of Account 219 at End of Preceding Quarter/Year
6	Balance of Account 219 at Beginning of Current Year
7	Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8	Current Quarter/Year to Date Changes in Fair Value
9	Total (lines 7 and 8)								1,066,087,097	1,066,087,097
10	Balance of Account 219 at End of Current Quarter/Year

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION
Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.
Line No.	Classification (a)	Total Company For the Current Year/Quarter Ended (b)	Electric (c)	Gas (d)	Other (Specify) (e)	Other (Specify) (f)	Other (Specify) (g)	Common (h)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlantInServiceAbstract In Service
3	UtilityPlantInServiceClassified Plant in Service (Classified)	38,020,748,357	38,020,748,357
4	UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases	7,849,772	7,849,772
5	UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold
6	UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified	1,064,604,469	1,064,604,469
7	UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified
8	UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7)	39,093,202,598	39,093,202,598
9	UtilityPlantLeasedToOthers Leased to Others
10	UtilityPlantHeldForFutureUse Held for Future Use	99,953,769	99,953,769
11	ConstructionWorkInProgress Construction Work in Progress	1,220,404,574	1,220,404,574
12	UtilityPlantAcquisitionAdjustment Acquisition Adjustments	2,774,314,255	2,774,314,255
13	UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12)	43,187,875,196	43,187,875,196
14	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion	12,206,668,092	12,206,668,092
15	UtilityPlantNet Net Utility Plant (13 less 14)	30,981,207,104	30,981,207,104
16	DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17	AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service:
18	DepreciationUtilityPlantInService Depreciation	11,280,254,100	11,280,254,100
19	AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService Amortization and Depletion of Producing Natural Gas Land and Land Rights
20	AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService Amortization of Underground Storage Land and Land Rights
21	AmortizationOfOtherUtilityPlantUtilityPlantInService Amortization of Other Utility Plant	777,039,377	777,039,377
22	DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21)	12,057,293,477	12,057,293,477
23	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract Leased to Others
24	DepreciationUtilityPlantLeasedToOthers Depreciation
25	AmortizationAndDepletionUtilityPlantLeasedToOthers Amortization and Depletion
26	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers Total Leased to Others (24 & 25)
27	DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract Held for Future Use
28	DepreciationUtilityPlantHeldForFutureUse Depreciation
29	AmortizationUtilityPlantHeldForFutureUse Amortization
30	DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29)
31	AbandonmentOfLeases Abandonment of Leases (Natural Gas)
32	AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment	149,374,615	149,374,615
33	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32)	12,206,668,092	12,206,668,092

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No.	Description of item (a)	Balance Beginning of Year (b)	Changes during Year Additions (c)	Changes during Year Amortization (d)	Changes during Year Other Reductions (Explain in a footnote) (e)	Balance End of Year (f)
1	Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1)
2	Fabrication
3	Nuclear Materials
4	Allowance for Funds Used during Construction
5	(Other Overhead Construction Costs, provide details in footnote)
6	SUBTOTAL (Total 2 thru 5)
7	Nuclear Fuel Materials and Assemblies
8	In Stock (120.2)
9	In Reactor (120.3)
10	SUBTOTAL (Total 8 & 9)
11	Spent Nuclear Fuel (120.4)
12	Nuclear Fuel Under Capital Leases (120.6)
13	(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)
14	TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)
15	Estimated Net Salvage Value of Nuclear Materials in Line 9
16	Estimated Net Salvage Value of Nuclear Materials in Line 11
17	Est Net Salvage Value of Nuclear Materials in Chemical Processing
18	Nuclear Materials held for Sale (157)
19	Uranium
20	Plutonium
21	Other (Provide details in footnote)
22	TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21)

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
Report below the original cost of electric plant in service according to the prescribed accounts. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of the prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No.	Account (a)	Balance Beginning of Year (b)	Additions (c)	Retirements (d)	Adjustments (e)	Transfers (f)	Balance at End of Year (g)
1	1. INTANGIBLE PLANT
2	(301) Organization	80,375					80,375
3	(302) Franchise and Consents
4	(303) Miscellaneous Intangible Plant	1,172,518,522	412,477,542	247,998,085			1,336,997,979
5	TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)	1,172,598,897	412,477,542	247,998,085			1,337,078,354
6	2. PRODUCTION PLANT
7	A. Steam Production Plant
8	(310) Land and Land Rights
9	(311) Structures and Improvements
10	(312) Boiler Plant Equipment
11	(313) Engines and Engine-Driven Generators
12	(314) Turbogenerator Units
13	(315) Accessory Electric Equipment
14	(316) Misc. Power Plant Equipment
15	(317) Asset Retirement Costs for Steam Production
16	TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)
17	B. Nuclear Production Plant
18	(320) Land and Land Rights
19	(321) Structures and Improvements
20	(322) Reactor Plant Equipment
21	(323) Turbogenerator Units
22	(324) Accessory Electric Equipment
23	(325) Misc. Power Plant Equipment
24	(326) Asset Retirement Costs for Nuclear Production
25	TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)
26	C. Hydraulic Production Plant
27	(330) Land and Land Rights
28	(331) Structures and Improvements
29	(332) Reservoirs, Dams, and Waterways
30	(333) Water Wheels, Turbines, and Generators
31	(334) Accessory Electric Equipment
32	(335) Misc. Power Plant Equipment
33	(336) Roads, Railroads, and Bridges
34	(337) Asset Retirement Costs for Hydraulic Production
35	TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)
36	D. Other Production Plant
37	(340) Land and Land Rights
38	(341) Structures and Improvements
39	(342) Fuel Holders, Products, and Accessories
40	(343) Prime Movers
41	(344) Generators
42	(345) Accessory Electric Equipment
43	(346) Misc. Power Plant Equipment
44	(347) Asset Retirement Costs for Other Production
44.1	(348) Energy Storage Equipment - Production
45	TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)
46	TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)
47	3. Transmission Plant
48	(350) Land and Land Rights	189,527,542					189,527,542
48.1	(351) Energy Storage Equipment - Transmission
49	(352) Structures and Improvements	789,306,978	77,781,835	1,025,897	2,189,021		863,873,895
50	(353) Station Equipment	3,142,002,375	42,328,139	6,025,721	7,215,496		3,171,089,297
51	(354) Towers and Fixtures	272,198,248	4,258,768		255,762		267,683,718
52	(355) Poles and Fixtures	981,356,114	67,161,452	12,254	2,267,254		1,046,238,058
53	(356) Overhead Conductors and Devices	704,151,980	5,747,338	394,492	1,409,700		708,095,126
54	(357) Underground Conduit	231,905,697	3,042,582	33,188	413,733		234,501,358
55	(358) Underground Conductors and Devices	563,494,421	13,228,185	240,527	1,232,171		575,249,908
56	(359) Roads and Trails	20,721,058	4,652,422		61,685		25,311,795
57	(359.1) Asset Retirement Costs for Transmission Plant	7,580,060		108,770	2,400,422		9,871,712
58	TOTAL Transmission Plant (Enter Total of lines 48 thru 57)	6,902,244,473	209,683,185	7,840,849	12,644,400		7,091,442,409
59	4. Distribution Plant
60	(360) Land and Land Rights	76,051,352	2,884			185,458	76,233,926
61	(361) Structures and Improvements	906,673,194	65,532,652	678,191	362,704		971,164,951
62	(362) Station Equipment	4,066,720,575	233,833,367	12,937,384	2,896,138		4,284,720,420
63	(363) Energy Storage Equipment – Distribution	274,704					274,704
64	(364) Poles, Towers, and Fixtures	3,027,620,827	195,192,010	19,305,842	8,314,719	4,390	3,195,196,666
65	(365) Overhead Conductors and Devices	4,528,132,363	263,176,119	65,705,042	13,084,828	189,354	4,712,329,258
66	(366) Underground Conduit	1,136,372,636	59,583,107	2,649,744	2,324,604	3,005	1,190,984,400
67	(367) Underground Conductors and Devices	8,199,109,515	404,888,781	36,430,435	23,509,826	14,718	8,544,043,317
68	(368) Line Transformers	1,629,783,265	144,333,121	43,176,526	373,428	6,130	1,730,560,302
69	(369) Services	1,475,194,205	31,602,884	4,879,193	3,572,087		1,498,345,809
70	(370) Meters	858,073,532	14,990,380	5,946,561		202,807	867,320,158
71	(371) Installations on Customer Premises	89,805,426	1,577,864	72,995	269,280		91,041,015
72	(372) Leased Property on Customer Premises	824,003	64,293				759,710
73	(373) Street Lighting and Signal Systems	210,198,209	12,981,986	3,388,898	620,994		219,170,303
74	(374) Asset Retirement Costs for Distribution Plant	33,911,783		45,699	9,613,300		43,479,384
75	TOTAL Distribution Plant (Enter Total of lines 60 thru 74)	26,238,745,589	1,427,625,094	195,216,510	45,715,308	185,458	27,425,624,323
76	5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77	(380) Land and Land Rights
78	(381) Structures and Improvements
79	(382) Computer Hardware
80	(383) Computer Software
81	(384) Communication Equipment
82	(385) Miscellaneous Regional Transmission and Market Operation Plant
83	(386) Asset Retirement Costs for Regional Transmission and Market Oper
84	TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85	6. General Plant
86	(389) Land and Land Rights	38,257,667					38,257,667
87	(390) Structures and Improvements	816,198,036	16,401,965	5,322,355			827,277,646
88	(391) Office Furniture and Equipment	168,562,231	28,839,258	27,843,194			169,558,295
89	(392) Transportation Equipment	481,967,231	54,846,808	17,587,396			519,226,643
90	(393) Stores Equipment	8,264,150					8,264,150
91	(394) Tools, Shop and Garage Equipment	282,784,901	15,617,328	33,551,547			264,850,682
92	(395) Laboratory Equipment	17,528,058	3,398,256	123,835			20,802,479
93	(396) Power Operated Equipment	7,740,974					7,740,974
94	(397) Communication Equipment	1,271,557,585	91,609,446	31,984,213			(c) 1,331,182,818
95	(398) Miscellaneous Equipment	23,708,471	8,732,903	1,369,867			31,071,507
96	SUBTOTAL (Enter Total of lines 86 thru 95)	3,116,569,304	219,445,964	117,782,407			3,218,232,861
97	(399) Other Tangible Property
98	(399.1) Asset Retirement Costs for General Plant	13,338,192		363,313			12,974,879
99	TOTAL General Plant (Enter Total of lines 96, 97, and 98)	3,129,907,496	219,445,964	118,145,720			3,231,207,740
100	TOTAL (Accounts 101 and 106)	37,443,496,455	2,269,231,785	569,201,164	58,359,708	185,458	39,085,352,826
101	(102) Electric Plant Purchased (See Instr. 8)
102	(Less) (102) Electric Plant Sold (See Instr. 8)
103	(103) Experimental Plant Unclassified
104	TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)	37,443,496,455	2,269,231,785	569,201,164	(a) 58,359,708	(b) 185,458	39,085,352,826

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: ElectricPlantInServiceAdjustments


The plant in-service adjustments of $12,013,721 is the result of periodic reviews of, and changes to, the Company's asset retirement obligations, intercompany transfers for ($373,429) and an adjustment to FERC account 101 for ($70,000,000) which represents a reduction in plant balance per the February 11, 2025 Settlement Agreement between ComEd and the FERC Office of Enforcement to resolve the labor and labor-related overheads accounting matter in Docket Nos. FA 21-5-000 and FA 21-5-001. Of the ($70,000,000) adjustment, ($54,955,180) was recorded to Distribution and ($15,044,820) was recorded to Transmission.

(b) Concept: ElectricPlantInServiceTransfers


Represents net transfers from Account 105 (Plant Held for Future Use) of $185,458.


Of the balance reported in Account 397 (Communication Equipment) of $1,331,182,818 - 30.18% of such amount is directly assignable to the Transmission function and 69.82% of such amount is directly assignable to the Distribution function.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No.	LesseeName Name of Lessee (a)	IndicationOfAssociatedCompany * (Designation of Associated Company) (b)	LeaseDescription Description of Property Leased (c)	CommissionAuthorization Commission Authorization (d)	ExpirationDateOfLease Expiration Date of Lease (e)	ElectricPlantLeasedToOthers Balance at End of Year (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47	TOTAL

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No.	ElectricPlantHeldForFutureUseDescription Description and Location of Property (a)	ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate Date Originally Included in This Account (b)	ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate Date Expected to be used in Utility Service (c)	ElectricPlantHeldForFutureUse Balance at End of Year (d)
1	Land and Rights:
2	Transmission Plant (Land and/or Rights):
3	Charter Grove TSS	12/31/2006	(a) 01/01/2030	637,355
4	Cherry Valley-Silver Lake	06/30/1973	01/01/2035	1,827,050
5	Chicago-Northwestern R. R.	12/31/2001	01/01/2035	1,567,260
6	Eakin Creek TSS	09/30/1996	01/01/2035	2,670,479
7	Goodings Grove-Indiana Widening/Crete TSS	09/30/1971	01/01/2033	1,206,117
8	Manville-Pontiac	11/30/1972	01/01/2035	528,398
9	Plano-Charter Grove	06/30/1975	01/01/2030	4,343,302
10	Plato Center - 1	01/31/1992	01/01/2035	426,467
11	Sugar Grove-Blackberry	03/31/1991	01/01/2035	408,473
12	Waukegan Station 354kv Switchyard	12/31/2006	01/01/2035	799,826
13	Wayne-Itasca	12/31/1970	01/01/2035	4,099,384
14	Wilton Center-Joliet	05/31/1973	01/01/2035	352,474
15	Sugar Grove TSS	12/31/2012	01/01/2035	720,587
16	Sawyer TSS	12/31/2019	01/01/2030	441,267
17	Midway Court TSS	04/30/2024	01/01/2028	10,486,744
18	18 items less than $250,000 each			1,303,236
19
20
21
22
23
24
25
26
27
28
21	Other Property:
22	Distribution Plant (Land and/or Rights):
23	Plato Center - 2	01/31/1992	01/01/2037	617,255
24	Rutland TDC	09/30/1996	01/01/2037	372,830
25	Lakeview - 1141 W. Diversey	12/01/2020	01/01/2029	11,729,191
26	Land - Aurora to Elgin-Kane	11/01/2021	01/01/2030	41,557,075
27	Plymouth Court	07/31/2022	01/01/2033	4,715,679
28	Jefferson GIS	12/31/2021	01/01/2028	7,718,755
29	31 items less than $250,000			1,416,284
30	General Plant (Land and\or RIghts)
31	1 items less than $250,000			8,281
47	TOTAL			99,953,769

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate


The expected dates to be used in utility service are estimates and are subject to change.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
Report below descriptions and balances at end of year of projects in process of construction (107). Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts). Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No.	ConstructionWorkInProgressProjectDescription Description of Project (a)	ConstructionWorkInProgress Construction work in progress - Electric (Account 107) (b)
1	Intangible Plant
2	Major projects:
3	EU GIS CORE SW	45,799,781
4	Apollo Phase 2 W/O WPT SW	35,595,710
5	ADMS - Cap Software #2 SW	25,963,092
6	EMS Upgrade - SW	6,302,808
7	Apollo Boundary Apps SW	5,184,733
8	oneMDS Mobile Dispatch - SW	4,644,794
9	PowerPlan Upgrade SW	3,680,940
10	EU GIS DQ SW	3,388,799
11	oneMDS Mobile Dispatch SW RL4	2,660,607
12	ADMS - SW	1,763,429
13	ComEd DERMS 2 SW	1,640,426
14	Predictive Grid Platform	1,531,823
15	EU Reliability and Auto SW	1,477,593
16	LCS-MEU SW	1,415,026
17	GIS Transmission SW	1,386,713
18	ComED VO Refresh SW	1,352,820
19	GDVA Implementation SW	1,271,878
20	Apollo Boundary Apps Cl	1,159,710
21	Other Projects	(a) 7,579,720
22	Transmission Plant
23	TSS 135 Elmhurst 345kV GIS	62,634,572
24	TSS 51 McCook 138kV Line	36,246,099
25	Upgrade 138kV Line 0108	34,506,929
26	TSS 116 Goodings Grove - Insta	20,466,737
27	UA HQ Data Center TSS184	13,742,945
28	Upgrade 345kV L97008	9,042,548
29	INSTALL 3RD TR (40MVA) AT TDC2	8,623,729
30	TSS46 Des Plaines TR83 Rpl	7,398,914
31	TSS184 345kV GIS and Cntrl Eqp	7,303,657
32	Prime Data Center	6,197,130
33	Rebuild L15518-TSS132 & TSS133	4,849,257
34	TSS 101 Itasca - Install 345-1	4,597,619
35	TSS192 Ridgeland - TR71 Matrl	4,002,559
36	OCC Static Switch Repair	3,886,043
37	CyrusOne Aurora TR at TSS111	3,688,863
38	TSS78 Franklin Park L3705 PST	3,643,343
39	Prj Unity-138kV L0901 Brdg PWR	2,960,684
40	TDC 505 Oak Park Hardening	2,925,803
41	STA11 Fisk Cap Bank	2,754,808
42	TSS 76 Blue Island 345 kV Expa	2,567,600
43	L2105 Line Rebuild	2,474,919
44	L19414 S. Pecatonic break	1,857,586
45	L17105 Wood Pole Replacement	1,724,984
46	L17401 Leak Repair	1,699,539
47	Pine TUG 138kV L10108-T	1,521,950
48	Pine TUG 138kV L10109-T	1,519,437
49	L17113 Wood Pole Replacement	1,499,167
50	L19414 Wood Pole Replacement	1,482,089
51	TSS37 Natoma 138kV Hardening	1,455,426
52	TSS242 Greenleaf Station Build	1,405,098
53	TSS184 Elk Grove 345kV TR 81	1,381,378
54	NTT Data Center - TSS101-T	1,357,864
55	GIS Building - TSS51 138kV GIS	1,338,280
56	TSS101 Itasca 138kV Cap Bank	1,279,383
57	362439 TSS 300 Keslinger 138kV	1,191,424
58	TSS110 Devon 138kV Hardening	1,178,214
59	TSS184 Elk Grove-345kV TR 82	1,143,702
60	L7615 Wood Replacement	1,098,891
61	Auto Transformers at TSS192	1,098,705
62	TSS 146 Sandwich 138kV Station	1,075,059
63	Rebuild 69SK6	1,057,225
64	TSS177 Burnham TR84 Replacemen	1,039,008
65	Other Projects - 1	(b) 36,909,533
66	Distribution Plant
67	Major Projects:
68	Cloud HQ Data Center-ESSE410	26,537,475
69	Project Post - ESS E 535	25,411,092
70	TSS 82 Crosby Intel Sub	24,446,336
71	Aligned Data Cented 505 NW	17,136,323
72	Project Circle ESSE552	17,006,733
73	1680 E TOUHY	8,798,343
74	3P190201-Z11884	8,129,787
75	Retire 4kV Fdrs W405 W406 W438	7,936,741
76	CyrusOne Wood Dale -ESS	7,604,259
77	CyrusOne Aurora TR at TSS111 - 1	7,503,007
78	TSS64 Bellwood 12kV Switchgear	7,130,147
79	TSS104 Ford City Intel Sub	6,570,544
80	Indirects-Removal for Budget	6,172,866
81	TSS 181 Compass Data Center	6,127,641
82	Stream Data Center	5,929,709
83	NTT Data Center ESS	5,737,497
84	Project Post - L21408	5,729,710
85	4P223700-DCE27 Arlington Hts’	5,251,044
86	L1863/L1864/L1865 Relocation	4,994,455
87	Microsoft CHI07 Data Center	4,975,120
88	Aligned ESS at Elk Grove	4,767,499
89	Project Post - L21403	4,687,161
90	National Digital Gateway ESS	4,623,054
91	L19203 HPFF Replacement	4,405,045
92	Spare TR67MVA (3-Wind)Aligned	4,397,392
93	MediterraneanDataCenter-L18402	4,291,343
94	MediterraneanDataCenter-L18409	4,271,245
95	5P2302: new feeder D3429	3,925,475
96	77698:7P230001-TSS113 UPG Dist	3,848,593
97	Prime Data Center Trans/34KV	3,806,957
98	6P230800 - 4:12 conversions	3,738,245
99	New Feeder Z17449	3,365,887
100	2021 REACTS STA13 FOH	3,289,654
101	3P211002-56TH144 12 KV CONV	2,974,272
102	362780: STATE & LAKE/CDOT ZN1	2,957,700
103	Project Circle NEW ESS	2,944,266
104	CSX Midway Airport L5103 Reloc	2,938,110
105	1P240004- Replace 69kV bus	2,926,294
106	L13349- River Crossing INS CBL	2,822,799
107	1P190001-Install 5th TR	2,809,259
108	1050 W. Van Buren - Perm	2,707,588
109	7P240001-TDC375 new trans	2,701,421
110	505 Northwest - Phase 2	2,668,879
111	Northpoint Elwood Phase 2	2,656,441
112	MR 2022 1300 GROUP NETCENTERS	2,483,429
113	2021 REACTS STA13_2 FOH	2,365,642
114	8P250001 TDC446 Lansing 12kV	2,201,753
115	Iron Mountain TSS46 DesPlaines	2,152,467
116	Spare TR 40MVA (2-Wind) Ridgld	2,059,444
117	34kV Resiliency-L19342 Part 1	2,035,205
118	12 kV DA Baseline X1492	2,028,218
119	7P230800 - B169	1,994,715
120	Yukon Proj-Walmart ColdStorage	1,982,410
121	TSS192 Ridgeland TR71 Replcmnt	1,932,333
122	Prime Data Center Elk Grove	1,849,339
123	1P250001-New Rockwell TDC	1,831,348
124	RT 53 & RT 56 DUPAGE COUNTY	1,778,723
125	6P240007 TSS149 12kV	1,676,460
126	STREAM 1 ADD SERVICE	1,620,970
127	Project Barb_PD_7P231400	1,584,802
128	NB 1501 SOUTH WELLS PERM	1,584,177
129	TSS184 Third TR	1,536,185
130	Edged Energy Data Center - ESS	1,519,999
131	12 kV DA IP2 X3980	1,510,834
132	1P240400 SC Work on X4866X	1,506,638
133	ITN 362197: Woodstock IL 47	1,504,288
134	GRIP 2016 12kV Y8256	1,480,343
135	644 Madison, Oak Park - Perm	1,449,538
136	1955 W Hastings - PERM	1,440,104
137	5P230001 TSS131 Bus Exp	1,427,707
138	520 S MAPLE	1,376,761
139	362293 :FR-S ELGIN S MCLEAN BL	1,375,072
140	12 kV DA X8442	1,369,254
141	12kV DA Program - Z17450	1,317,674
142	PQ Meters	1,316,936
143	Compass TUG 138kV L18517	1,312,425
144	1P250200-New fdr to rlv TSS84	1,278,533
145	CyrusOne ButterfieldDataCenter	1,276,044
146	TDC452 Replace TR71	1,235,805
147	363158:Orland Park- IL 7/South	1,233,621
148	362342 : Lisle, Warrenville Rd	1,223,338
149	8001 W Belmont - Phase 2 & 3	1,191,128
150	28 E Garfield-Washington Park	1,172,648
151	8P233700 4:12kV G53 & G56	1,170,397
152	220 E Illinois Station Relief	1,166,927
153	3P240200 : New Fdr Z1412	1,161,373
154	KARE ESS	1,160,541
155	5P220402 Boring D3427 feeder	1,128,884
156	PD# 1P241000 - NETWORK TIES	1,107,479
157	1P240410-Relieve X1496	1,106,089
158	Spare TR 40MVA TSS141-2	1,092,457
159	Spare TR 40MVA TSS141	1,092,457
160	SBA EDGE LINE EXTENSION	1,084,106
161	3P230200: Long lead NSC	1,072,594
162	Spare TR 50MVA (Compct) E Frkf	1,054,562
163	917 W Fulton - Perm Service	1,052,268
164	PD# 3P233700 IP2 4/12kV THRP42	1,032,207
165	12kV DA Program - X8443	1,013,422
166	CloudHQ - E524 & E5220 Feeder	1,008,560
167	Other Projects - 2	(c) 196,113,710
168	General Plant
169	2020 REACTS STA18-TSS60 DFR	7,176,165
170	2019 REACTS TSS157-DCK15 BBF	6,744,927
171	REACTS 1C224302 TSS30-TSS30-03	6,117,523
172	Maywood Lab expansion	5,634,755
173	HEALTH - Analytics DAP HW	3,839,477
174	EUN Refresh 2023 HW	3,815,649
175	REACTS DF-TSS89-TSS118-LINK 2	3,609,955
176	2019 REACTS STA22-STA16 BBF	3,488,408
177	2020 REACTS TSS193-TSS193 DFR	3,365,062
178	2021 REACTS DF-STA13-STA13-01	3,315,185
179	REACTS DIXON BBF LINK 5	3,044,292
180	Long Term Performance Plan	2,921,206
181	Long Term Performance Plan - 1	2,608,100
182	2020 REACTS TSS60-TDC461-2 DFR	2,571,397
183	REACTS 1C224303TDC714-TDC714-1	2,521,611
184	Long Term Performance Plan - 2	2,496,120
185	Long Term Performance Plan - 3	2,439,658
186	Long Term Performance Plan - 4	2,401,723
187	REACTS1C224303 TDC714-TDC714-2	2,372,134
188	Long Term Performance Plan - 5	2,289,454
189	2019 REACTS TDC294-TSS154 BBF	2,263,942
190	Long Term Performance Plan - 6	2,227,485
191	Long Term Performance Plan - 7	2,154,675
192	Long Term Performance Plan - 8	2,145,482
193	2020 REACTS TDC447 to TSS73	2,093,062
194	2019 REACTS TSS945-TSS70 BBF	2,028,659
195	ADMS Task Force - HW	1,936,991
196	Project Post - ESS E 535 - 1	1,821,157
197	NORTH VO TDC212 NORTHBROOK	1,782,072
198	REACTS CRE BBF LINK 1	1,761,156
199	Long Term Performance Plan - 9	1,709,513
200	ATO Monitoring- Chicago	1,673,773
201	2020 REACTS TDC409-TSS474 BFR	1,561,765
202	2020 REACnTS TDC206	1,505,477
203	REACTS1C224303 TDC714-TDC714-4	1,475,194
204	Chicago North EVCS 2023	1,456,651
205	Long Term Performance Plan - 10	1,440,326
206	Private LTE Cores & Initia HW	1,406,040
207	FIBER TSS160-TSS165-01.01 ROC	1,368,137
208	2019 REACTS STA16-TDC294 BBF	1,289,117
209	REACTS 1C224302 STA13-TSS30-01	1,209,273
210	Long Term Performance Plan - 11	1,194,545
211	2021 REACTS BF-TDC469-TDC531	1,173,639
212	2021 REACTS DF-STA13_2-TSS63-1	1,166,886
213	2020 REACTS BF-SS851-SS895	1,166,718
214	REACTS 1C224302 TSS30-TSS30-1	1,164,147
215	2020 REACTS BF-TSS63-SS851	1,157,691
216	REACTS 1C224302 TSS30-TSS38-01	1,146,251
217	SS674 12kV Relay Upgd SCADA	1,107,198
218	S211 - Customer Target BESS	1,089,910
219	2021 REACTS DF-STA13-STA13_2-2	1,072,343
220	2020 REACTS DF-TSS60-TSS115-01	1,056,660
221	S385 - Customer Target BESS	1,028,970
222	2019 REACTS TSS86 to TSS946 BB	1,015,093
223	Other Projects - 3	(d) 62,664,922
43	Total	1,220,404,574

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: ConstructionWorkInProgress


There are 33 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.

(b) Concept: ConstructionWorkInProgress


There are 450 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.


There are 2,555 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.

(d) Concept: ConstructionWorkInProgress


There are 543 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
Explain in a footnote any important adjustments during year. Explain in a footnote any difference between the amount for book cost of plant retired, Line 12, column (c), and that reported for electric plant in service, page 204, column (d), excluding retirements of non-depreciable property. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No.	Item (a)	Total (c + d + e) (b)	Electric Plant in Service (c)	Electric Plant Held for Future Use (d)	Electric Plant Leased To Others (e)
Section A. Balances and Changes During Year
1	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance Beginning of Year	10,663,341,920	10,663,341,920
2	Depreciation Provisions for Year, Charged to
3	DepreciationExpenseExcludingAdjustments (403) Depreciation Expense	1,052,277,392	1,052,277,392
4	DepreciationExpenseForAssetRetirementCosts (403.1) Depreciation Expense for Asset Retirement Costs	1,830,160	1,830,160
5	ExpensesOfElectricPlantLeasedToOthers (413) Exp. of Elec. Plt. Leas. to Others
6	TransportationExpensesClearing Transportation Expenses-Clearing	30,881,681	30,881,681
7	OtherClearingAccounts Other Clearing Accounts
8	OtherAccounts Other Accounts (Specify, details in footnote):
9.1	Other Accounts (Specify, details in footnote):	5,143,225	(a) 5,143,225
10	DepreciationProvision TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)	1,090,132,458	1,090,132,458
11	Net Charges for Plant Retired:
12	BookCostOfRetiredPlant Book Cost of Plant Retired	315,979,540	(b) 315,979,540
13	CostOfRemovalOfPlant Cost of Removal	157,100,973	157,100,973
14	SalvageValueOfRetiredPlant Salvage (Credit)	4,504,001	4,504,001
15	NetChargesForRetiredPlant TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)	468,576,512	468,576,512
16	OtherAdjustmentsToAccumulatedDepreciation Other Debit or Cr. Items (Describe, details in footnote):
17.1	Other Debit or Cr. Items (Describe, details in footnote):	4,125,984	(c) 4,125,984
18	BookCostOfAssetRetirementCosts Book Cost or Asset Retirement Costs Retired	517,782	517,782
19	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)	11,280,254,100	11,280,254,100
Section B. Balances at End of Year According to Functional Classification
20	AccumulatedDepreciationSteamProduction Steam Production
21	AccumulatedDepreciationNuclearProduction Nuclear Production
22	AccumulatedDepreciationHydraulicProductionConventional Hydraulic Production-Conventional
23	AccumulatedDepreciationHydraulicProductionPumpedStorage Hydraulic Production-Pumped Storage
24	AccumulatedDepreciationOtherProduction Other Production
25	AccumulatedDepreciationTransmission Transmission	1,859,483,326	1,859,483,326
26	AccumulatedDepreciationDistribution Distribution	7,979,349,453	7,979,349,453
27	AccumulatedDepreciationRegionalTransmissionAndMarketOperation Regional Transmission and Market Operation
28	AccumulatedDepreciationGeneral General	1,441,421,321	(d) 1,441,421,321
29	AccumulatedProvisionForDepreciationOfElectricUtilityPlant TOTAL (Enter Total of lines 20 thru 28)	11,280,254,100	11,280,254,100

FOOTNOTE DATA

(a) Concept: OtherAccounts



Accumulated Depreciation on asset retirement costs charged primarily to Account 182.3	$	5,143,225

(b) Concept: BookCostOfRetiredPlant


Retirements per Page 219 for Account 108	$	315,979,540
Retirements per Page 204 for Plant in Service	569,201,164
Difference	$	253,221,624

Details of Difference:
Retirement of Asset Retirement Costs for FIN 47	$	517,782
Retirement of Leasehold improvements charged to Account 111 - Accumulated Provisions for Amortization	4,705,757
Retirement of Software charged to Account 111	247,998,085
Total	$	253,221,624


Adjustments to Account 108 - Accumulated Provision for Depreciation - for revisions recorded to the Asset Retirement Obligations and ARO Regulatory Assets	$	(4,125,984)

(d) Concept: AccumulatedDepreciationGeneral


The amount of accumulated depreciation associated with Account 397 (Communication Equipment) as of December 31, 2024 is $889,067,578 - 30.18% of such amount is directly assignable to the Transmission function, and 69.82% of such amount is directly assignable to the Distribution function

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
Report below investments in Account 123.1, Investments in Subsidiary Companies. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f). Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No.	DescriptionOfInvestmentsInSubsidiaryCompanies Description of Investment (a)	DateOfAcquisitionInvestmentsInSubsidiaryCompanies Date Acquired (b)	DateOfMaturityInvestmentsInSubsidiaryCompanies Date of Maturity (c)	InvestmentInSubsidiaryCompanies Amount of Investment at Beginning of Year (d)	EquityInEarningsOfSubsidiaryCompanies Equity in Subsidiary Earnings of Year (e)	InterestAndDividendRevenueFromInvestments Revenues for Year (f)	InvestmentInSubsidiaryCompanies Amount of Investment at End of Year (g)	InvestmentGainLossOnDisplosal Gain or Loss from Investment Disposed of (h)
1	Commonwealth Edison Company of Indiana, Inc.	12/31/1962
2	Common Stock, no par value (III. C.C. Docket Number 46967)			6,189,528			6,189,528
3	Other Capital Stock Transactions - Net			34,161,813			34,161,813
4	Undistributed Earnings			55,676,181	8,756,536	4,837,864	59,594,853
5	Subtotal			96,027,522	8,756,536	4,837,864	99,946,194
6	ComEd Financing III
7	Common Securities (III. C. C. Docket Number 02-0562)			6,186,000			6,186,000
8	Undistributed Earnings			115,661	392,811	392,811	115,661
9	Subtotal			6,301,661	392,811	392,811	6,301,661
10	EdiSun, LLC
11	Ownership Interest			61,592			61,592
12	RITELine Illinois, LLC
13	Ownership Interest			20,537			20,537
42	Total Cost of Account 123.1 $ 12,375,528		Total	102,288,128	9,149,347	5,230,675	106,206,800

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

MATERIALS AND SUPPLIES
For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No.	Account (a)	Balance Beginning of Year (b)	Balance End of Year (c)	Department or Departments which Use Material (d)
1	Fuel Stock (Account 151)
2	Fuel Stock Expenses Undistributed (Account 152)
3	Residuals and Extracted Products (Account 153)
4	Plant Materials and Operating Supplies (Account 154)
5	Assigned to - Construction (Estimated)	268,199,577	(a) 181,978,717
6	Assigned to - Operations and Maintenance
7	Production Plant (Estimated)
8	Transmission Plant (Estimated)	4,642,775	7,595,643	Transmission
9	Distribution Plant (Estimated)	12,718,935	108,115,374	Distribution
10	Regional Transmission and Market Operation Plant (Estimated)
11	Assigned to - Other (provide details in footnote)
12	TOTAL Account 154 (Enter Total of lines 5 thru 11)	285,561,287	297,689,734
13	Merchandise (Account 155)
14	Other Materials and Supplies (Account 156)
15	Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)
16	Stores Expense Undistributed (Account 163)
17
18
19
20	TOTAL Materials and Supplies	285,561,287	297,689,734

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesConstruction


Assigned to - Construction (Estimated)
Transmission Plant (Estimated)	$	47,487,920
Distribution Plant (Estimated)	134,490,797
Assigned to - Construction (Estimated)	$	181,978,717

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	SO2 Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)
5	Returned by EPA
6
7
8
9
10
11
12
13
14
15	Total
16
17	Relinquished During Year:
18	Charges to Account 509
19	Other:
20	Allowances Used
20.1	Allowances Used
21	Cost of Sales/Transfers:
22
23
24
25
26
27
28	Total
29	Balance-End of Year
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)
33	Net Sales Proceeds (Other)
34	Gains
35	Losses
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year
37	Add: Withheld by EPA
38	Deduct: Returned by EPA
39	Cost of Sales
40	Balance-End of Year
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)
44	Net Sales Proceeds (Other)
45	Gains
46	Losses

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	NOx Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)
5	Returned by EPA
6
7
8
9
10
11
12
13
14
15	Total
16
17	Relinquished During Year:
18	Charges to Account 509
19	Other:
20	Allowances Used
20.1	Allowances Used
21	Cost of Sales/Transfers:
22
23
24
25
26
27
28	Total
29	Balance-End of Year
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)
33	Net Sales Proceeds (Other)
34	Gains
35	Losses
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year
37	Add: Withheld by EPA
38	Deduct: Returned by EPA
39	Cost of Sales
40	Balance-End of Year
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)
44	Net Sales Proceeds (Other)
45	Gains
46	Losses

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfExtraordinaryPropertyLoss Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).] (a)	ExtraordinaryPropertyLossesNotYetRecognized Total Amount of Loss (b)	ExtraordinaryPropertyLossesRecognized Losses Recognized During Year (c)	ExtraordinaryPropertyLossesWrittenOffAccountCharged Account Charged (d)	ExtraordinaryPropertyLossesWrittenOff Amount (e)	ExtraordinaryPropertyLosses Balance at End of Year (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
20	TOTAL

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)] (a)	UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized Total Amount of Charges (b)	UnrecoveredPlantAndRegulatoryStudyCostsRecognized Costs Recognized During Year (c)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged Account Charged (d)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff Amount (e)	UnrecoveredPlantAndRegulatoryStudyCosts Balance at End of Year (f)
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49	TOTAL

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

Transmission Service and Generation Interconnection Study Costs
Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies. List each study separately. In column (a) provide the name of the study. In column (b) report the cost incurred to perform the study at the end of period. In column (c) report the account charged with the cost of the study. In column (d) report the amounts received for reimbursement of the study costs at end of period. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.	DescriptionOfStudyPerformed Description (a)	StudyCostsIncurred Costs Incurred During Period (b)	StudyCostsAccountCharged Account Charged (c)	StudyCostsReimbursements Reimbursements Received During the Period (d)	StudyCostsAccountReimbursed Account Credited With Reimbursement (e)
1	Transmission Studies
2	PJM AE1-070 Elwood 345 kV Faci	2,152	408.1	68,509	456
3	PJM AE1-070 Elwood 345 kV Faci	6,832	926
4	PJM AE1-070 Elwood 345 kV Faci	43,485	561.6
5	PJM AE1-070 Elwood 345 kV Faci	16,040	921
20	Total	68,509		68,509
21	Generation Studies
22	AE1-114 PJM Facilities Study	4,034	408.1	142,665	456
23	AE1-114 PJM Facilities Study	95,836	561.7
24	AE1-114 PJM Facilities Study	12,197	926
25	AE1-114 PJM Facilities Study	30,598	921
26	PJM AE2-173: MCLEAN 345 KV	2,191	408.1	74,397	456
27	PJM AE2-173: MCLEAN 345 KV	48,912	561.7
28	PJM AE2-173: MCLEAN 345 KV	6,741	926
29	PJM AE2-173: MCLEAN 345 KV	16,553	921
30	PJM AE2-341 Facility Study	3,531	408.1	133,062	456
31	PJM AE2-341 Facility Study	90,953	561.7
32	PJM AE2-341 Facility Study	10,797	926
33	PJM AE2-341 Facility Study	27,781	921
34	PJM AF1-030 Facility Study	2,178	408.1	74,109	456
35	PJM AF1-030 Facility Study	48,772	561.7
36	PJM AF1-030 Facility Study	6,714	926
37	PJM AF1-030 Facility Study	16,445	921
38	AF-2041 Nelson-Elec Junc 345kV	4,702	408.1	160,434	456
39	AF-2041 Nelson-Elec Junc 345kV	105,541	561.7
40	AF-2041 Nelson-Elec Junc 345kV	14,750	926
41	AF-2041 Nelson-Elec Junc 345kV	35,441	921
42	PJM AF2-128 Crescent Ridge-Cor	39	408.1	959	456
43	PJM AF2-128 Crescent Ridge-Cor	533	561.7
44	PJM AF2-128 Crescent Ridge-Cor	125	926
45	PJM AF2-128 Crescent Ridge-Cor	262	921
46	AF2-199 Nelson-Elec Junc 345kV	2,768	408.1	99,938	456
47	AF2-199 Nelson-Elec Junc 345kV	66,728	561.7
48	AF2-199 Nelson-Elec Junc 345kV	8,733	926
49	AF2-199 Nelson-Elec Junc 345kV	21,709	921
50	AF2-349 Garden Prairie 345 kV	3,859	408.1	132,307	456
51	AF2-349 Garden Prairie 345 kV	88,774	561.7
52	AF2-349 Garden Prairie 345 kV	11,605	926
53	AF2-349 Garden Prairie 345 kV	28,069	921
54	PJM MISO J955 FACILITIES STUDY	1,135	408.1	29,975	456
55	PJM MISO J955 FACILITIES STUDY	16,951	561.7
56	PJM MISO J955 FACILITIES STUDY	3,887	926
57	PJM MISO J955 FACILITIES STUDY	8,040	921
58	MISO J1377 - PJM Facilities	2,301	408.1	95,304	456
59	MISO J1377 - PJM Facilities	65,130	561.7
60	MISO J1377 - PJM Facilities	7,848	926
61	MISO J1377 - PJM Facilities	20,025	921
62	AF2-027 Facility Study	42	408.1	1,125	456
63	AF2-027 Facility Study	646	561.7
64	AF2-027 Facility Study	144	926
65	AF2-027 Facility Study	293	921
66	PJM AF2-363 Cherry Valley-Glid	169	408.1	4,480	456
67	PJM AF2-363 Cherry Valley-Glid	2,565	561.7
68	PJM AF2-363 Cherry Valley-Glid	578	926
69	PJM AF2-363 Cherry Valley-Glid	1,168	921
70	PJM AF1-090 Facilities Study	4,965	408.1	199,008	456
71	PJM AF1-090 Facilities Study	133,356	561.7
72	PJM AF1-090 Facilities Study	16,849	926
73	PJM AF1-090 Facilities Study	43,838	921
74	PJM AF2-366 Facilities Study	4,298	408.1	161,852	456
75	PJM AF2-366 Facilities Study	106,222	561.7
76	PJM AF2-366 Facilities Study	14,422	926
77	PJM AF2-366 Facilities Study	36,910	921
78	PJM AG1-512	42	408.1	1,086	456
79	PJM AG1-512	619	561.7
80	PJM AG1-512	141	926
81	PJM AG1-512	284	921
82	PJM AF2-031 Facility Study	300	408.1	10,710	456
83	PJM AF2-031 Facility Study	6,845	561.7
84	PJM AF2-031 Facility Study	1,036	926
85	PJM AF2-031 Facility Study	2,529	921
86	AF2-252 PJM Facilities Study	274	408.1	9,967	456
87	AF2-252 PJM Facilities Study	6,510	561.7
88	AF2-252 PJM Facilities Study	945	926
89	AF2-252 PJM Facilities Study	2,238	921
90	AF2-352 PJM Facilities Study	604	408.1	18,013	456
91	AF2-352 PJM Facilities Study	10,909	561.7
92	AF2-352 PJM Facilities Study	2,042	926
93	AF2-352 PJM Facilities Study	4,458	921
94	PJM J982 Facilities Study	2,548	408.1	93,380	456
95	PJM J982 Facilities Study	60,673	561.7
96	PJM J982 Facilities Study	8,644	926
97	PJM J982 Facilities Study	21,515	921
98	TC01-PJM Transition Cycle 1	30,271	408.1	687,845	456
99	TC01-PJM Transition Cycle 1	365,607	561.7
100	TC01-PJM Transition Cycle 1	97,343	926
101	TC01-PJM Transition Cycle 1	194,624	921
102	AF2-095 Wilmington-Davis Creek	2,912	408.1	96,192	456
103	AF2-095 Wilmington-Davis Creek	62,875	561.7
104	AF2-095 Wilmington-Davis Creek	8,922	926
105	AF2-095 Wilmington-Davis Creek	21,483	921
106	PJM AF2-392 Facilities Study	4,406	408.1	173,261	456
107	PJM AF2-392 Facilities Study	119,698	561.7
108	PJM AF2-392 Facilities Study	13,483	926
109	PJM AF2-392 Facilities Study	35,674	921
110	PJM AF2-441 Facilities Study	4,025	408.1	147,009	456
111	PJM AF2-441 Facilities Study	99,120	561.7
112	PJM AF2-441 Facilities Study	12,280	926
113	PJM AF2-441 Facilities Study	31,584	921
114	AE1-172 Loretto-Wilton Study	4,507	408.1	148,969	456
115	AE1-172 Loretto-Wilton Study	96,228	561.7
116	AE1-172 Loretto-Wilton Study	14,152	926
117	AE1-172 Loretto-Wilton Study	34,082	921
118	AE2-107 Haumesser Rd PJM Study	131	408.1	3,067	456
119	AE2-107 Haumesser Rd PJM Study	1,659	561.7
120	AE2-107 Haumesser Rd PJM Study	412	926
121	AE2-107 Haumesser Rd PJM Study	865	921
122	PJM AE2-223 McLean 345kV Facil	2,606	408.1	84,366	456
123	PJM AE2-223 McLean 345kV Facil	54,275	561.7
124	PJM AE2-223 McLean 345kV Facil	8,065	926
125	PJM AE2-223 McLean 345kV Facil	19,420	921
126	PJM AE2-261 Facilities Study	3,769	408.1	137,690	456
127	PJM AE2-261 Facilities Study	93,142	561.7
128	PJM AE2-261 Facilities Study	11,565	926
129	PJM AE2-261 Facilities Study	29,214	921
130	PJM AE2-321 Facilities Study	3,615	408.1	134,098	456
131	PJM AE2-321 Facilities Study	91,280	561.7
132	PJM AE2-321 Facilities Study	11,068	926
133	PJM AE2-321 Facilities Study	28,135	921
134	AF1-048 Belvidere Morengo	2,380	408.1	77,587	456
135	AF1-048 Belvidere Morengo	50,604	561.7
136	AF1-048 Belvidere Morengo	7,303	926
137	AF1-048 Belvidere Morengo	17,300	921
138	PJM AF1-200 Facilities Study	3,942	408.1	127,758	456
139	PJM AF1-200 Facilities Study	82,817	561.7
140	PJM AF1-200 Facilities Study	12,243	926
141	PJM AF1-200 Facilities Study	28,756	921
142	PJM AF1-252 Facilities Study	39	408.1	966	456
143	PJM AF1-252 Facilities Study	536	561.7
144	PJM AF1-252 Facilities Study	126	926
145	PJM AF1-252 Facilities Study	265	921
146	PJM AF1-253 Facilities Study	66	408.1	1,599	456
147	PJM AF1-253 Facilities Study	888	561.7
148	PJM AF1-253 Facilities Study	208	926
149	PJM AF1-253 Facilities Study	437	921
150	AF1-280 Nelson Lee County Stud	4,317	408.1	150,705	456
151	AF1-280 Nelson Lee County Stud	100,507	561.7
152	AF1-280 Nelson Lee County Stud	13,380	926
153	AF1-280 Nelson Lee County Stud	32,501	921
154	AF1-281 Nelson & Lee County	177	408.1	3,387	456
155	AF1-281 Nelson & Lee County	1,751	561.7
156	AF1-281 Nelson & Lee County	515	926
157	AF1-281 Nelson & Lee County	944	921
158	PJM AF1-296 Facilities Study	3,578	408.1	113,029	456
159	PJM AF1-296 Facilities Study	74,674	561.7
160	PJM AF1-296 Facilities Study	10,856	926
161	PJM AF1-296 Facilities Study	23,921	921
162	PJM AF1-314 Facilities Study	5,542	408.1	198,275	456
163	PJM AF1-314 Facilities Study	133,401	561.7
164	PJM AF1-314 Facilities Study	16,859	926
165	PJM AF1-314 Facilities Study	42,473	921
166	PJM AF1-318 Facilities Study	213	408.1	6,730	456
167	PJM AF1-318 Facilities Study	5,029	561.7
168	PJM AF1-318 Facilities Study	53	926
169	PJM AF1-318 Facilities Study	1,967	921
170	PJM AF2-034 Facilities Study	2,749	408.1	80,097	456
171	PJM AF2-034 Facilities Study	49,426	561.7
172	PJM AF2-034 Facilities Study	8,500	926
173	PJM AF2-034 Facilities Study	19,422	921
174	PJM AF2-069 Facilities Study	1,576	408.1	57,635	456
175	PJM AF2-069 Facilities Study	37,991	561.7
176	PJM AF2-069 Facilities Study	5,148	926
177	PJM AF2-069 Facilities Study	12,920	921
178	PJM AF2-070 Facilities Study	1,576	408.1	45,507	456
179	PJM AF2-070 Facilities Study	29,907	561.7
180	PJM AF2-070 Facilities Study	4,676	926
181	PJM AF2-070 Facilities Study	9,348	921
182	PJM AF2-096 Facilities Study	4,427	408.1	134,743	456
183	PJM AF2-096 Facilities Study	85,523	561.7
184	PJM AF2-096 Facilities Study	13,763	926
185	PJM AF2-096 Facilities Study	31,030	921
186	PJM AF2-142 Facilities Study	2,069	408.1	64,309	456
187	PJM AF2-142 Facilities Study	41,166	561.7
188	PJM AF2-142 Facilities Study	6,410	926
189	PJM AF2-142 Facilities Study	14,664	921
190	AF2-143 Powerton- Nevada 345kV	2,110	408.1	65,160	456
191	AF2-143 Powerton- Nevada 345kV	41,586	561.7
192	AF2-143 Powerton- Nevada 345kV	6,509	926
193	AF2-143 Powerton- Nevada 345kV	14,955	921
194	PJM AF2-182 Facilities Study	1,810	408.1	58,289	456
195	PJM AF2-182 Facilities Study	37,766	561.7
196	PJM AF2-182 Facilities Study	5,615	926
197	PJM AF2-182 Facilities Study	13,098	921
198	PJM AF2-183- Nelson Lee County	202	408.1	4,638	456
199	PJM AF2-183- Nelson Lee County	2,480	561.7
200	PJM AF2-183- Nelson Lee County	639	926
201	PJM AF2-183- Nelson Lee County	1,317	921
202	AF2-200 Nelson Elec Junc 345kV	2,731	408.1	99,799	456
203	AF2-200 Nelson Elec Junc 345kV	66,718	561.7
204	AF2-200 Nelson Elec Junc 345kV	8,621	926
205	AF2-200 Nelson Elec Junc 345kV	21,729	921
206	PJM AF2-201 Facilities Study	4,651	408.1	162,684	456
207	PJM AF2-201 Facilities Study	108,660	561.7
208	PJM AF2-201 Facilities Study	14,257	926
209	PJM AF2-201 Facilities Study	35,116	921
210	AF2-225 McLean 345kV	2,072	408.1	71,832	456
211	AF2-225 McLean 345kV	47,517	561.7
212	AF2-225 McLean 345kV	6,446	926
213	AF2-225 McLean 345kV	15,797	921
214	PJM AF2-226 Facilities Study	1,747	408.1	57,776	456
215	PJM AF2-226 Facilities Study	37,787	561.7
216	PJM AF2-226 Facilities Study	5,455	926
217	PJM AF2-226 Facilities Study	12,787	921
218	PJM AF2-319 Facilities Study	1,824	408.1	60,418	456
219	PJM AF2-319 Facilities Study	39,565	561.7
220	PJM AF2-319 Facilities Study	5,689	926
221	PJM AF2-319 Facilities Study	13,340	921
222	PJM AF2-350	2,833	408.1	97,354	456
223	PJM AF2-350	64,495	561.7
224	PJM AF2-350	8,685	926
225	PJM AF2-350	21,341	921
226	PJM AF2-393 Facilities Study	1,960	408.1	61,553	456
227	PJM AF2-393 Facilities Study	39,423	561.7
228	PJM AF2-393 Facilities Study	6,076	926
229	PJM AF2-393 Facilities Study	14,094	921
230	PJM AF2-394 Facilities Study	1,663	408.1	54,297	456
231	PJM AF2-394 Facilities Study	35,483	561.7
232	PJM AF2-394 Facilities Study	5,165	926
233	PJM AF2-394 Facilities Study	11,986	921
234	PJM AG1-005 Facilities Study	3,196	408.1	125,039	456
235	PJM AG1-005 Facilities Study	86,452	561.7
236	PJM AG1-005 Facilities Study	9,768	926
237	PJM AG1-005 Facilities Study	25,623	921
238	PJM AG1-118 Facilities Study	3,690	408.1	135,605	456
239	PJM AG1-118 Facilities Study	92,155	561.7
240	PJM AG1-118 Facilities Study	11,256	926
241	PJM AG1-118 Facilities Study	28,504	921
242	PJM AG1-120 Facilities Study	2,127	408.1	65,436	456
243	PJM AG1-120 Facilities Study	41,722	561.7
244	PJM AG1-120 Facilities Study	6,551	926
245	PJM AG1-120 Facilities Study	15,036	921
246	PJM AG1-127 Facilities Study	3,102	408.1	107,404	456
247	PJM AG1-127 Facilities Study	71,437	561.7
248	PJM AG1-127 Facilities Study	9,528	926
249	PJM AG1-127 Facilities Study	23,334	921
250	PJM AG1-236 Facilities Study	2,463	408.1	72,944	456
251	PJM AG1-236 Facilities Study	45,725	561.7
252	PJM AG1-236 Facilities Study	7,555	926
253	PJM AG1-236 Facilities Study	17,201	921
254	PJM AG1-298 Facilities Study	4,738	408.1	132,527	456
255	PJM AG1-298 Facilities Study	86,455	561.7
256	PJM AG1-298 Facilities Study	13,734	926
257	PJM AG1-298 Facilities Study	27,600	921
258	PJM AG1-374 Facilities Study	3,642	408.1	124,405	456
259	PJM AG1-374 Facilities Study	82,607	561.7
260	PJM AG1-374 Facilities Study	11,227	926
261	PJM AG1-374 Facilities Study	26,929	921
262	PJM AG1-434 Facilities Study	4,435	408.1	177,951	456
263	PJM AG1-434 Facilities Study	124,052	561.7
264	PJM AG1-434 Facilities Study	13,448	926
265	PJM AG1-434 Facilities Study	36,016	921
266	PJM AG1-435 Facilities Study	3,685	408.1	138,622	456
267	PJM AG1-435 Facilities Study	94,577	561.7
268	PJM AG1-435 Facilities Study	11,166	926
269	PJM AG1-435 Facilities Study	29,194	921
270	PJM AG1-460 Facilities Study	2,030	408.1	69,069	456
271	PJM AG1-460 Facilities Study	45,813	561.7
272	PJM AG1-460 Facilities Study	6,214	926
273	PJM AG1-460 Facilities Study	15,012	921
274	PJM AG1-462 Facilities Study	3,889	408.1	142,447	456
275	PJM AG1-462 Facilities Study	96,211	561.7
276	PJM AG1-462 Facilities Study	11,860	926
277	PJM AG1-462 Facilities Study	30,487	921
278	PJM AG1-535 Facilities Study	1,736	408.1	64,068	456
279	PJM AG1-535 Facilities Study	42,992	561.7
280	PJM AG1-535 Facilities Study	5,491	926
281	PJM AG1-535 Facilities Study	13,849	921
282	PJM AG1-553 Facilities Study	4,218	408.1	155,125	456
283	PJM AG1-553 Facilities Study	105,281	561.7
284	PJM AG1-553 Facilities Study	12,852	926
285	PJM AG1-553 Facilities Study	32,774	921
286	PJM Facilities Studies	2,682	408.1	56,385	456
287	PJM Facilities Studies	29,360	561.7
288	PJM Facilities Studies	8,923	926
289	PJM Facilities Studies	15,420	921
39	Total	6,478,457		6,478,422
40	Grand Total	6,546,966		6,546,931

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

OTHER REGULATORY ASSETS (Account 182.3)
Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Assets being amortized, show period of amortization.
				CREDITS
Line No.	DescriptionAndPurposeOfOtherRegulatoryAssets Description and Purpose of Other Regulatory Assets (a)	OtherRegulatoryAssets Balance at Beginning of Current Quarter/Year (b)	IncreaseDecreaseInOtherRegulatoryAssets Debits (c)	OtherRegulatoryAssetsWrittenOffAccountCharged Written off During Quarter/Year Account Charged (d)	OtherRegulatoryAssetsWrittenOffRecovered Written off During the Period Amount (e)	OtherRegulatoryAssets Balance at end of Current Quarter/Year (f)
1	(a) Capitalized Employee Incentive Payments	5,097,129		407.3	287,485	4,809,644
2	Deferred Asset Retirement Obligation Costs	104,466,505	9,658,857	403.1	1,815,755	112,309,607
3	Cash Flow Swap Settlement Costs	4,718,859		427	519,507	4,199,352
4	MGP Remediation Costs	286,207,129	18,612,815	407.3	29,517,318	275,302,626
5	Renewable Energy Swaps	133,632,802	1,464,305	242 / 253	3,678,237	131,418,870
6	AMI Meter Accelerated Depreciation	28,072,525		407.3	15,150,370	12,922,155
7	Carbon Mitigation Credit	672,543,020	719,900,940	557	1,213,188,860	179,255,100
8	Rate Case	5,221,171	6,796,828	407.3	3,004,500	9,013,499
9	Uncollectible Accounts Expense - Under Recovery	78,454,238	61,906,395	407.4	14,328,360	126,032,273
10	Distribution Service Costs	886,581,574	64,275,953	407.3, 440, 442, 444, 446	215,393,053	735,464,474
11	Energy Efficiency Costs	1,691,436,816	435,219,508	407.3, 440, 442, 444, 446	236,797,267	1,889,859,057
12	Capital Lease Excess Depreciation	1,809,785	145,634			1,955,419
13	Purchased Receivables Program - Under Recovery	14,376,844	14,081,778	407.3	69,632	28,388,990
14	Purchased Electricity - Under Recovery	15,412,326	17,502,293	555	32,914,619
15	Distributed Generation Rebate Costs	108,432,814	74,269,943	407.3, 440, 442, 444, 446	10,921,831	171,780,926
16	Transmission Costs - Under Recovery	14,804,278	4,792,912			19,597,190
17	Parallel Operation of Retail Customer Generating Facilities Community Supply	2,872,854		555	2,872,854
18	Zero Emissions Program	58,111,921		557	54,603,205	3,508,716
19	Deferred Income Taxes	284,311,635	6,593,399			290,905,034
20	Interval Meter Usage Data		23,618			23,618
44	TOTAL	4,396,564,225	1,435,245,178		1,835,062,853	3,996,746,550

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Line Item

Rate Order Docket Number Or Recovery Mechanism

Amortization Period

Capitalized Employee Incentive Payments

ICC Docket 01-0423

3/31/2003 - 7/31/2043

Deferred Asset Retirement Obligation Costs

Rider DSPR, Multi-Year Rate Plan & Transmission Formula Rate

Over the life of related assets

Cash Flow Swap Settlement Costs

Rider DSPR, Multi-Year Rate Plan & Transmission Formula Rate

3/15/2002 - 1/31/2033

MGP Remediation Costs

ICC Docket 05-0597

1/1/2007 - 12/31/2025

Renewable Energy Swaps

ICC Docket No. 09-0373

6/1/2012 - 5/1/2032

AMI Meter Accelerated Depreciation

ICC Docket 12-0298

1/1/2014-12/31/2028

Carbon Mitigation Credit

CEJA

4 months from period end

Rate Case

CEJA

4 years (2024 - 2027)

Uncollectible Accounts Expense - Under Recovery

ICC Docket No. 09-0433 & 20-0309

12 months from each June

Distribution Service Costs

EIMA & FEJA
SB2408 - Clean Energy Law - Distribution Formula Transition for year 2022 & 2023

3-5 years

Energy Efficiency Costs

FEJA

Over the measurable life of efficiency measures

Capital Lease Excess Depreciation

Rider DSPR & Multi-Year Rate Plan

2039 - 2053

Purchased Receivables Program - Under Recovery

ICC Docket 10-0138

1/1/2011 - 12/31/2020

Purchased Electricity - Under Recovery

ICC Docket No. 05-0159 & 18-1824

4 months from period end

Distributed Generation Rebate Costs

FEJA

15 years

Transmission Costs - Under Recovery

FERC Docket ER07-583

12 months from each June

Parallel Operation of Retail Customer Generating Facilities Community Supply

ICC Docket 22-0305

Not determined yet

Zero Emissions Program

FEJA

9 months from each September

Interval Meter Usage Data

ICC Docket 23-0773

6/1/2025 - 3/31/2030

Deferred Income Taxes

ICC Order 18-0034 / FERC Order ER19-5 dated 4/26/2019

Over the life of related assets

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

MISCELLANEOUS DEFFERED DEBITS (Account 186)
Report below the particulars (details) called for concerning miscellaneous deferred debits. For any deferred debit being amortized, show period of amortization in column (a) Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
				CREDITS
Line No.	Description of Miscellaneous Deferred Debits (a)	Balance at Beginning of Year (b)	Debits (c)	Credits Account Charged (d)	Credits Amount (e)	Balance at End of Year (f)
1	Accumulated under/Over recoveries -local government compliance causes	398,120	1,286,205	(a) Various	1,357,765	326,560
2	Vacation pay and payroll taxes pending proper accounting distribution	25,782,540	309,790,361	242	312,895,407	22,677,494
3	Long-Term contracting services	288,672	112,973	517, 528	195,369	206,276
4	Cook County Forest Preserve District License Fees to be amortized through 2027	3,342,361		589	685,683	2,656,678
5	Pension Asset	1,217,181,252	6,501,392	184, 926	58,964,313	1,164,718,331
6	Long Term receivable from Constellation Energy Generation, LLC (formerly Exelon Generation Company, LLC) (SFAS 143, Regulatory Liability offset)	2,954,412,180	1,165,933,958	254.1	340,678,976	3,779,667,162
7	Long Term receivable from the MBA Plan	2,734,498	80,565,407	143, 253	80,198,059	3,101,846
8	Credit facilities - ICC fees and other issuance costs to be amortized through 2027	303,598	1,653,241	131, 141	657,207	1,299,632
9	ICC Financing Authority Fees	5,681,803	287,820	143, 181	1,607,820	4,361,803
10	Insurance recoveries related to third party claims	7,230,846	31,379,255	925	6,503,849	32,106,252
11	Estimated Illinois Distribution Tax Refund	4,061,217	9,114,211	143, 236, 408.1	4,208,612	8,966,816
12	Long Term Restricted Cash	173,548,216	39,010,807	134	171,913,575	40,645,448
13	Long-Term Receivable Related to the FERC 494 Refund	5,278,640		254	5,278,640
14	Microgrid Prepayment	364,239	5,099,287	535	75,322	5,388,204
15	Adjustable Block REC Prepayments	575,273,878	297,864,958	165	11,697	873,127,139
16	Long-term portion of receivables from deferred payment agreements	1,389,745	1,735,644	142	3,010,047	115,342
17	Rochelle Franchise Fees to be amortized through 2070	1,380,000		253	30,000	1,350,000
18	Illinois Solar for All Program REC Prepayment	14,966,782	19,833,898	165	918,583	33,882,097
19	REACTS Fiber Program	139,337		107	119,913	19,424
20	Skydio Cloud 3yr Subscription Purchase	93,712		514	93,712
21	I&M Canal Fees to be amortized through June 2033	430,100		931	50,600	379,500
22	Maywood Outdoor Lab Program	816,074	206,501	107	582,796	439,779
23	Minor Items	2,141,210	481,686,774	(b) Various	481,930,265	1,897,719
47	Miscellaneous Work in Progress	228,940				208,872
48	Deferred Regulatory Comm. Expenses (See pages 350 - 351)
49	TOTAL	4,997,467,960				5,977,542,374

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged


Accumulated under/over recoveries are offset in Accounts 107000, 108030, 535250, 615000, 143300,410090, 131000, 232100, and 503000.

(b) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged


Minor items are offset in Accounts 107000, 131100, 182890, 184100, 184200, 228200, 232000, 232900, 241000, 242000, 242200, 242300, 514000, 514062, 517010, 535000, 535160 and 535170.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

ACCUMULATED DEFERRED INCOME TAXES (Account 190)
Report the information called for below concerning the respondent’s accounting for deferred income taxes. At Other (Specify), include deferrals relating to other income and deductions.
Line No.	DescriptionOfAccumulatedDeferredIncomeTax Description and Location (a)	AccumulatedDeferredIncomeTaxes Balance at Beginning of Year (b)	AccumulatedDeferredIncomeTaxes Balance at End of Year (c)
1	Electric
2		(a) 1,006,863,343	871,112,133
7	Other
8	TOTAL Electric (Enter Total of lines 2 thru 7)	1,006,863,343	(b) 871,112,133
9	Gas
15	Other
16	TOTAL Gas (Enter Total of lines 10 thru 15)
17.1	Other (Specify)
17	Other (Specify)
18	TOTAL (Acct 190) (Total of lines 8, 16 and 17)	1,006,863,343	871,112,133

Notes

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxes


Account 190 Federal Inc. Activity:
410 Debits	$	85,465,050
411 Credits	25,632,926
Net Debit/(Credits)	$	59,832,124

Account 190 State Inc. Activity:
410 Debits	$	6,936,701
411 Credits	12,813,090
Net Debit/(Credits)	$	(5,876,389)

Account 190 Activity B/S Only:
Debits	$	—
Credits	81,795,475
Net Adjustments	$	(81,795,475)

Net Change	$	(135,751,210)

(b) Concept: AccumulatedDeferredIncomeTaxes


Account 190 Description:	Beginning Balance		Ending Balance
Accrued Benefits	$	4,018,069	$	41,203,399
Accrued Bonuses & Incentives	43,529,546		1,653,695
Accrued Legal	14,253		—
Accrued Severance	1,019,238		1,875,484
Accrued Vacation	10,314,195		11,573,641
Accrued Workers' Compensation	22,654,211		34,389,182
Accrued OPEB	47,474,964		46,188,384
Allowance for Doubtful Accounts	23,640,736		38,936,707
Charitable Contribution Carryforward	—		—
Corporate Alternative Minimum Tax	118,023,568		47,215,886
Deferred Compensation	8,499,188		8,237,241
Deferred Revenue	2,405,758		2,114,350
Environmental Cleanup Costs	13,150,719		161,707
Manufactured Gas Plants	73,091,938		80,959,200
Obsolete Materials	1,809,907		1,311,768
Other - 190	9,892,629		10,542,851
Regulatory Liability	620,745,033		539,101,260
State Income Taxes	4,294,062		3,513,745
Unamortized Investment Tax Credit	2,285,329		2,133,633
Total	$	1,006,863,343	$	871,112,133

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

CAPITAL STOCKS (Account 201 and 204)
Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No.	Class and Series of Stock and Name of Stock Series (a)	Number of Shares Authorized by Charter (b)	Par or Stated Value per Share (c)	Call Price at End of Year (d)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares (e)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount (f)	Held by Respondent As Reacquired Stock (Acct 217) Shares (g)	Held by Respondent As Reacquired Stock (Acct 217) Cost (h)	Held by Respondent In Sinking and Other Funds Shares (i)	Held by Respondent In Sinking and Other Funds Amount (j)
1	Common Stock (Account 201)
2	(a) Total Common Stock	250,000,000	12.50		127,021,417	1,587,297,245
7	Total	250,000,000			127,021,417	1,587,297,245
8	Preferred Stock (Account 204)
9
10
11
12	Total

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: CapitalStockDescription

ComEd had 59,970 and 60,032 warrants outstanding to purchase ComEd common stock at December 31, 2024 and 2023, respectively. The warrants entitle the holders to convert such warrants into common stock of ComEd at a conversion rate of one share of common stock for three warrants. At December 31, 2024 and 2023, 19,990 and 20,011 shares of common stock, respectively, were reserved for the conversion of warrants.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2024-12-31

Year/Period of Report

End of:

2024

Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No.	Item (a)	Amount (b)
1	DonationsReceivedFromStockholdersAbstract Donations Received from Stockholders (Account 208)
2	DonationsReceivedFromStockholders Beginning Balance Amount
3.1	IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders Increases (Decreases) from Sales of Donations Received from Stockholders
4	DonationsReceivedFromStockholders Ending Balance Amount
5	ReductionInParOrStatedValueOfCapitalStockAbstract Reduction in Par or Stated Value of Capital Stock (Account 209)
6	ReductionInParOrStatedValueOfCapitalStock Beginning Balance Amount
7.1	IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8	ReductionInParOrStatedValueOfCapitalStock Ending Balance Amount
9	GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10	GainOnResaleOrCancellationOfReacquiredCapitalStock Beginning Balance Amount
11.1	IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock
12	GainOnResaleOrCancellationOfReacquiredCapitalStock Ending Balance Amount
13	MiscellaneousPaidInCapitalAbstract Miscellaneous Paid-In Capital (Account 211)
14	MiscellaneousPaidInCapital Beginning Balance Amount	5,388,756,067
15.1	IncreasesDecreasesDueToMiscellaneousPaidInCapital Increases (Decreases) Due to Warrants	(a) 687
15.2	IncreasesDecreasesDueToMiscellaneousPaidInCapital Increases (Decreases) Due to Miscellaneous Paid-In Capital	226,556,660
16	MiscellaneousPaidInCapital Ending Balance Amount	(b) 5,615,312,040
17	OtherPaidInCapitalAbstract Other Paid in Capital
18	OtherPaidInCapitalDetail Beginning Balance Amount
19.1	IncreasesDecreasesInOtherPaidInCapital Increases (Decreases) in Other Paid-In Capital
20	OtherPaidInCapitalDetail Ending Balance Amount
40	OtherPaidInCapital Total	5,615,312,040

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2024-12-31

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: IncreasesDecreasesDueToMiscellaneousPaidInCapital


These amounts represent the balances related to the following types of Common Stock Purchase Warrants:
	Beginning Balance as of 12/31/2023	2024 YTD Activity	Ending Balance as of 12/31/2024
1971 Warrants	525,811	(26)	525,785
Series B Warrants	227,150	(661)	226,489
Total Warrants	752,961	(687)	752,274

(b) Concept: MiscellaneousPaidInCapital


The ending balance is comprised of $752,274 for Common Stock Purchase Warrants and $5,614,559,766 of other paid in capital. This other paid in capital amount represents the other paid in capital recognized from the indemnification from Exelon Corporation, the Respondent's parent, in related to the like-kind exchange transaction and to support expanded capital programs. See Note 7 - Income Taxes of the Notes to Financial Statements for additional information related to the like-kind exchanges.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

CAPITAL STOCK EXPENSE (Account 214)
Report the balance at end of the year of discount on capital stock for each class and series of capital stock. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No.	NameOfClassAndSeriesOfStock Class and Series of Stock (a)	CapitalStockExpense Balance at End of Year (b)
1	Common Stock	6,942,925
22	TOTAL	6,942,925

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

LONG-TERM DEBT (Account 221, 222, 223 and 224)
Report by Balance Sheet Account the details concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds, and in column (b) include the related account number. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received, and in column (b) include the related account number. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued, and in column (b) include the related account number. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (m). Explain in a footnote any difference between the total of column (m) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No.	ClassAndSeriesOfObligationCouponRateDescription Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates) (a)	RelatedAccountNumber Related Account Number (b)	Principal Amount of Debt Issued (c)	LongTermDebtIssuanceExpensePremiumOrDiscount Total Expense, Premium or Discount (d)	LongTermDebtIssuanceExpenses Total Expense (e)	LongTermDebtPremium Total Premium (f)	LongTermDebtDiscount Total Discount (g)	NominalDateOfIssue Nominal Date of Issue (h)	DateOfMaturity Date of Maturity (i)	AmortizationPeriodStartDate AMORTIZATION PERIOD Date From (j)	AmortizationPeriodEndDate AMORTIZATION PERIOD Date To (k)	Outstanding (Total amount outstanding without reduction for amounts held by respondent) (l)	Interest for Year Amount (m)
1	Bonds (Account 221)
2	100, 5.875%	221	350,000,000		3,525,036		1,526,000	01/22/2003	02/01/2033	01/22/2003	02/01/2033	253,600,000	14,899,000
3	103, 5.900%	221	325,000,000		3,488,737		2,044,250	03/06/2006	03/15/2036	03/06/2006	03/15/2036	325,000,000	19,175,000
4	103B, 5.900%	221	300,000,000		1,048,534		12,435,000	03/22/2007	03/15/2036	03/22/2007	03/15/2036	300,000,000	17,700,000
5	107, 6.450%	221	450,000,000		4,468,683		1,359,000	01/16/2008	01/15/2038	01/16/2008	01/15/2038	450,000,000	29,025,000
6	113, 3.800%	221	350,000,000		3,497,084		623,000	10/01/2012	10/01/2042	10/01/2012	10/01/2042	350,000,000	13,300,000
7	114, 4.600%	221	350,000,000		4,224,661		791,000	08/19/2013	08/15/2043	08/19/2013	08/15/2043	350,000,000	16,100,000
8	116, 4.700%	221	350,000,000		3,670,733		115,500	01/10/2014	01/15/2044	01/10/2014	01/15/2044	350,000,000	16,450,000
9	117, 3.100%	221	250,000,000		2,675,378		212,500	11/10/2014	11/01/2024	11/10/2014	11/01/2024		4,520,833
10	118, 3.700%	221	400,000,000		4,497,729			03/02/2015	03/01/2045	03/02/2015	03/01/2045	400,000,000	14,800,000
11	119, 4.350%	221	450,000,000		5,643,725		3,501,000	11/19/2015	11/15/2045	11/19/2015	11/15/2045	450,000,000	19,575,000
12	120, 2.550%	221	500,000,000		4,325,512			06/27/2016	06/15/2026	06/27/2016	06/15/2026	500,000,000	12,750,000
13	121, 3.650%	221	700,000,000		7,630,653		4,543,000	06/27/2016	06/15/2046	06/27/2016	06/15/2046	700,000,000	25,550,000
14	122, 2.950%	221	350,000,000		3,084,480		959,000	08/23/2017	08/15/2027	08/23/2017	08/15/2027	350,000,000	10,325,000
15	123, 3.750%	221	650,000,000		7,187,392		1,625,000	08/23/2017	08/15/2047	08/23/2017	08/15/2047	650,000,000	24,375,000
16	124, 4.000%	221	800,000,000		8,806,005		152,000	02/20/2018	03/01/2048	02/20/2018	03/01/2048	800,000,000	32,000,000
17	125, 3.700%	221	550,000,000		5,724,371		1,320,000	08/14/2018	08/15/2028	08/14/2018	08/15/2028	550,000,000	20,350,000
18	126, 4.000%	221	400,000,000		5,320,038		3,256,000	02/19/2019	03/01/2049	02/19/2019	03/01/2049	400,000,000	16,000,000
19	127, 3.200%	221	300,000,000		3,958,928		2,349,000	11/12/2019	11/15/2049	11/12/2019	11/15/2049	300,000,000	9,600,000
20	128, 2.200%	221	350,000,000		3,831,604		1,064,000	02/18/2020	03/01/2030	02/18/2020	03/01/2030	350,000,000	7,700,000
21	129, 3.000%	221	650,000,000		8,523,636		897,000	02/18/2020	03/01/2050	02/18/2020	03/01/2050	650,000,000	19,500,000
22	130, 3.125%	221	700,000,000		9,221,373		952,000	03/09/2021	03/15/2051	03/09/2021	03/15/2051	700,000,000	21,875,000
23	131, 2.750%	221	450,000,000		4,695,716		94,500	08/12/2021	09/01/2051	08/12/2021	09/01/2051	450,000,000	12,375,000
24	132, 3.150%	221	300,000,000		3,265,761		384,000	03/15/2022	03/15/2032	03/15/2022	03/15/2032	300,000,000	9,450,000
25	133, 3.850%	221	450,000,000		5,905,442		796,500	03/15/2022	03/15/2052	03/15/2022	03/15/2052	450,000,000	17,325,000
26	134, 4.900%	221	400,000,000		4,419,289		1,336,000	01/10/2023	02/01/2033	01/10/2023	02/01/2033	400,000,000	19,600,000
27	135, 5.300%	221	575,000,000		7,643,212		1,397,250	01/10/2023	02/01/2053	01/10/2023	02/01/2053	575,000,000	30,475,000
28	136, 5.300%	221	400,000,000		4,042,973		1,432,000	05/13/2024	06/01/2034	05/13/2024	06/01/2034	400,000,000	13,426,667
29	137, 5.650%	221	400,000,000		4,942,972		2,592,000	05/13/2024	06/01/2054	05/13/2024	06/01/2054	400,000,000	14,313,333
30	Subtotal		(a) 12,500,000,000		139,269,657		47,756,500					12,153,600,000	482,534,833
31	Reacquired Bonds (Account 222)
32
33
34
35	Subtotal
36	Advances from Associated Companies (Account 223)
37	Subordinated Deferrable Interest Debentures, 6.350%,	223	206,186,000		2,256,515		186,000	03/17/2003	03/15/2033	03/17/2003	03/15/2033	206,186,000	13,092,811
38	ComEd FInancing III
39	Subtotal		206,186,000		2,256,515		186,000					206,186,000	13,092,811
40	Other Long Term Debt (Account 224)
41
42
43
44	Subtotal
33	TOTAL		12,706,186,000									12,359,786,000	(b) 495,627,644

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: BondsPrincipalAmountIssued


Changes in Account 221 during the year:
	Issuances		Retirements
First Mortgage Bonds	$	800,000,000	$	250,000,000

The unamortized debt discount, premium or expense on reacquired debt are transferred to Account 189, Unamortized Loss on Reacquired Debt, or Account 257, Unamortized Gain on Reacquired Debt, as appropriate, and amortized to expense over the life of the new long-term debt issued to finance the debt redemption, and\or over the life of the original debt issuance if the debt is not refinanced.

(b) Concept: InterestExpenseOnLongTermDebtIssued


Total interest reported on Pages 256-257	$	495,627,644
Amortization of settled cash flow swaps - losses	519,508

Total for Accounts 427 and 430	$	496,147,152

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No.	Particulars (Details) (a)	Amount (b)
1	Net Income for the Year (Page 117)	1,066,087,097
2	Reconciling Items for the Year
3
4	Taxable Income Not Reported on Books
5
6
7
8
9	Deductions Recorded on Books Not Deducted for Return
10	See footnote for details	(a) 113,228,456
14	Income Recorded on Books Not Included in Return
15
16
17
18
19	Deductions on Return Not Charged Against Book Income
20	See footnote for details	(b) 431,726,233
27	Federal Tax Net Income	747,589,320
28	Show Computation of Tax:
29	Federal Income Tax at 21%	156,993,757
30	See footnote for details	(c) 83,056,956
31	Total	73,936,801
32	Federal Income Tax Acct 409.10	70,930,906
33	Federal Income Tax Acct 409.20	3,005,895

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: DeductionsRecordedOnBooksNotDeductedForReturn


Net Income for the Year (Page 117)	$	1,066,087,097
Federal Income Tax	(3,495,448)
State Income Tax	116,723,904
Pre-tax Book Income	$	1,179,315,553

(b) Concept: DeductionsOnReturnNotChargedAgainstBookIncome


Increase (Decrease) in Taxable Income Resulting From:
Removal Costs	$	(159,236,508)
Mixed Service Costs	(13,673,262)
Repair Allowance - Unit of Property	(440,754,759)
Bonus Depreciation	—
Depreciation	185,766,340
CIAC	144,192,488
AFUDC Equity	(37,985,228)
AFUDC Debt	(28,941,210)
Capitalized Interest	45,343,830
Gain/Loss on Disposition of Property	(31,696,349)
Other (Property)	57,260,985
Regulatory Assets & Liabilities	(93,063,451)
Pension/OPEB/SERP	(75,685,883)
Accrued Liabilities	188,510
Merger Commitment Deferrals	—
State Income Taxes Deductible	(64,324,889)
Deferred Revenue	(1,022,306)
Fines & Penalties	—
Other (Net)	81,905,459

Total Schedule M's	$	(431,726,233)


Federal Taxable Income	$	747,589,320

Computation of Federal Income Tax:
Federal Income Tax on Current Year Income (21%)	$	156,993,757
Current Corporate Minimum Tax	(72,525,518)
Income Tax Credits Utilized	(9,315,291)
Net Operating Loss Utilized	—
Return to Accrual	(3,079,205)
Uncertain Tax Positions	1,863,058
2016-2021 R&D Affirmative	—
Federal Income Tax	$	73,936,801

Federal Income Tax Account 409.10	$	70,930,906
Federal Income Tax Account 409.20	3,005,895
Total	$	73,936,801

Additional information in response to Instruction 2, Page 261:

The Respondent is a wholly-owned subsidiary of Exelon Corporation. The Respondent files a consolidated tax return with Exelon Corporation and Exelon Corporation's other subsidiaries. The consolidated federal income tax liability was allocated to the Respondent on a separate-return basis. Corporate Alternative Minimum Tax Adjustment: This adjustment represents the difference between regular tax calculated at 21% of taxable income to the Corporate Alternative Minimum Tax calculated at 15% of Adjusted Financial Statement Income.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (d). Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (l) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
					BALANCE AT BEGINNING OF YEAR					BALANCE AT END OF YEAR		DISTRIBUTION OF TAXES CHARGED
Line No.	DescriptionOfTaxesAccruedPrepaidAndCharged Kind of Tax (See Instruction 5) (a)	TypeOfTax Type of Tax (b)	TaxJurisdiction State (c)	TaxYear Tax Year (d)	TaxesAccrued Taxes Accrued (Account 236) (e)	PrepaidTaxes Prepaid Taxes (Include in Account 165) (f)	TaxesCharged Taxes Charged During Year (g)	TaxesPaid Taxes Paid During Year (h)	TaxAdjustments Adjustments (i)	TaxesAccrued Taxes Accrued (Account 236) (j)	PrepaidTaxes Prepaid Taxes (Included in Account 165) (k)	TaxesAccruedPrepaidAndCharged Electric (Account 408.1, 409.1) (l)	IncomeTaxesExtraordinaryItems Extraordinary Items (Account 409.3) (m)	AdjustmentsToRetainedEarnings Adjustment to Ret. Earnings (Account 439) (n)	TaxesIncurredOther Other (o)
1	Renewable Energy Tax	Other Taxes	IL	(a) 2024	682,521	0	4,617,145	4,614,638		685,028		4,617,145
2	Low Income Tax	Other Taxes	IL	(b) 2024	6,011,255	0	37,344,477	37,858,790		5,496,942		43,425,533			6,081,056
3	Energy Transition Assistance Charge	Other Taxes	IL	(c) 2024	7,753,418	0	60,591,136	59,083,264		9,261,290		60,591,136
4	Electricity Distribution Tax	Other Taxes	IL	(d) 2024	0	(p) 13,598,581	105,532,637	99,549,000	(q) 8,966,815	1,351,871		105,532,637
5	Chicago Infrastructure Maintenance Fee	Other Taxes	IL	(e) 2024	10,707,308	0	85,011,767	85,085,230		10,633,845		85,011,767
6	Evanston Infrastructure Maintenance Fee	Other Taxes	IL	(f) 2024	58,531	0	495,443	486,037		67,937		495,443
7	Municipal Utility Tax	Other Taxes	IL	(g) 2024	29,000	0	1,583,517	1,499,558		112,959		1,205,579			377,938
8	Cook County Parking Tax	Other Taxes	IL	(h) 2024	4,863	0	70,901	71,651		4,113		225			71,126
9	Chicago Transaction Tax	Other Taxes	IL	(i) 2024	42,761	0	336,612	233,919		145,454		204,524			132,088
10	Public Utility Fund	Other Taxes	IL	(j) 2024	1,487,341	0	2,411,176	2,707,790		1,190,727		2,411,176
11	Joliet Motor Fuel Tax	Other Taxes	IL	(k) 2024	113,607	0	11,216	11,216		113,607		11,216
12	Subtotal Other Tax				26,890,605	13,598,581	298,006,027	291,201,093	8,966,815	29,063,773		303,505,931			5,499,904
13	Unemployment Insurance (SUTA)	Unemployment Tax	IL	2023	21,873	0		21,873		0
14	Unemployment Insurance (SUTA)	Unemployment Tax	IL	2024	0	0	1,208,609	1,199,556		9,053		550,884			657,725
15	Unemployment Insurance (FUTA)	Unemployment Tax	Fed	2023	6,425	0		6,425		0
16	Unemployment Insurance (FUTA)	Unemployment Tax	Fed	2024	0	0	299,214	297,034		2,180		137,431			161,783
17	Subtotal Unemployment Tax				28,298	0	1,507,823	1,524,888		11,233		688,315			819,508
18	Use Tax	Sales And Use Tax	IL	(l) 2024	3,273,352	0	11,670,081	13,364,294		1,579,139		38,497			11,631,584
19	Chicago Use Tax	Sales And Use Tax	IL	(m) 2024	504,664	0	687,484	899,498		292,650		2,990			684,494
20	Sales Tax	Sales And Use Tax	IL	2024	0	180,980	392,067	200,773		10,314					392,067
21	Subtotal Sales And Use Tax				3,778,016	180,980	12,749,632	14,464,565		1,882,103		41,487			12,708,145
22	Federal Income Tax	Income Tax	Fed	(n) 2024	110,580,596	0	73,934,863	186,601,832	(r) 2,086,373	0		70,955,520			2,979,343
23	State Income Tax	Income Tax	IL	(o) 2024	21,045,827	0	59,328,226	62,244,847	(s) 1,059,032	17,070,174		61,713,309			2,385,083
24	Subtotal Income Tax				131,626,423	0	133,263,089	248,846,679	1,027,341	17,070,174		132,668,829			594,260
25	Federal Excise Tax - Heavy Highway	Excise Tax	Fed	2024	0	0	13,510	13,510		0		7,460			6,050
26	Subtotal Excise Tax				0	0	13,510	13,510		0		7,460			6,050
27	Franchise	Franchise Tax	IL	2023	0	1,529,997	1,529,997					1,529,997
28	Franchise	Franchise Tax	IL	2024	0	0	1,268,497	2,536,993			1,268,496	1,268,497
29	Subtotal Franchise Tax				0	1,529,997	2,798,494	2,536,993		0	1,268,496	2,798,494
30	Real Estate	Property Tax	IL	2023	36,255,000	0	3,825,527	32,429,473		0		3,825,527
31	Real Estate	Property Tax	IL	2024	0	0	35,161,953			35,161,953		34,841,458			320,495
32	Subtotal Other Property Tax				36,255,000	0	31,336,426	32,429,473		35,161,953		31,015,931			320,495
33	Vehicle License	Other License And Fees Tax	IL	2023	0	677,718	677,718			0					677,718
34	Vehicle License	Other License And Fees Tax	IL	2024	0	0	1,298,004	2,005,062		0	707,058				1,298,004
35	Vehicle License-Local	Other License And Fees Tax	IL	2023	0	67,027	67,027			0					67,027
36	Vehicle License-Local	Other License And Fees Tax	IL	2024	0	0	128,374	198,303		0	69,929				128,374
37	Subtotal Other License And Fees Tax				0	744,745	2,171,123	2,203,365		0	776,987				2,171,123
38	Insurance Contributions (FICA)	Payroll Tax	Fed	2023	12,713,580	0		12,713,580		0
39	Insurance Contributions (FICA)	Payroll Tax	Fed	2024	0	0	74,511,164	62,476,821		12,034,343		34,086,862			40,424,302
40	Subtotal Payroll Tax				12,713,580	0	74,511,164	75,190,401		12,034,343		34,086,862			40,424,302
40	TOTAL				211,291,922	16,054,303	556,357,288	668,410,967	9,994,156	95,223,579	2,045,483	504,813,309			51,543,979

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: TaxYear


The tax year for Renewable Energy Taxes accrued, prepaid, and charged during year also applies to the year 2023.

(b) Concept: TaxYear


The tax year for Low Income Taxes accrued, prepaid, and charged during year also applies to the year 2023.

The tax year for Energy Transition Assistance Charge Taxes accrued, prepaid, and charged during year also applies to the year 2023.

(d) Concept: TaxYear


The tax year for Electricity Distribution Taxes accrued, prepaid, and charged during year also applies to the year 2023.

(e) Concept: TaxYear


The tax year for Chicago Infrastructure Maintenance Fee Taxes accrued, prepaid, and charged during year also applies to the year 2023.

(f) Concept: TaxYear


The tax year for Evanston Infrastructure Maintenance Fee Taxes accrued, prepaid, and charged during year also applies to the year 2023.

(g) Concept: TaxYear


The tax year for Municipal Utility Taxes accrued, prepaid, and charged during year also applies to 2023 and prior years.

(h) Concept: TaxYear


The tax year for Cook County Parking Taxes accrued, prepaid, and charged during year also applies to the year 2023.

(i) Concept: TaxYear


The tax year for Chicago Transaction Taxes accrued, prepaid, and charged during year also applies to the year 2023.

(j) Concept: TaxYear

The tax year for Public Utility Fund Taxes accrued, prepaid, and charged during year also applies to the year 2023.

(k) Concept: TaxYear

The tax year for Joliet Motor Fuel Taxes accrued, prepaid, and charged during year also applies to the year 2023.

(l) Concept: TaxYear


The tax year for Use Taxes accrued, prepaid, and charged during year also applies to the year 2023.

(m) Concept: TaxYear


The tax year for Chicago Use Taxes accrued, prepaid, and charged during year also applies to the year 2023.

(n) Concept: TaxYear


The tax year for Federal Income Taxes accrued, prepaid, and charged during year also applies to the year 2023.

(o) Concept: TaxYear


The tax year for Illinois Income Taxes accrued, prepaid, and charged during year also applies to the year 2023.

(p) Concept: PrepaidTaxes


$4,061,217 recorded in Account 186 and $9,537,364 recorded in Account 143.

(q) Concept: TaxAdjustments


Reclass to FERC Account 186			$	8,966,815

(r) Concept: TaxAdjustments


Reclass to FERC Account 143			$	2,086,373

(s) Concept: TaxAdjustments


Reclass from FERC Account 283			$	(1,059,032)

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)
Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.
			Deferred for Year		Allocations to Current Year's Income
Line No.	Account Subdivisions (a)	Balance at Beginning of Year (b)	Account No. (c)	Amount (d)	Account No. (e)	Amount (f)	Adjustments (g)	Balance at End of Year (h)	Average Period of Allocation to Income (i)	ADJUSTMENT EXPLANATION (j)
1	Electric Utility
2	3%								—
3	4%	47,244			411.4	2,615		49,859	45
4	7%								—
5	10%	4,814,080			411.4	936,383		3,877,697	32
6	Illinois ITC	1,948,977	255	461,119	411.4	59,526		2,350,570	41
8	TOTAL Electric (Enter Total of lines 2 thru 7)	6,810,301		461,119		993,294		6,278,126
9	Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10										`
47	OTHER TOTAL
48	GRAND TOTAL	6,810,301		461,119		993,294		6,278,126

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

OTHER DEFERRED CREDITS (Account 253)
Report below the particulars (details) called for concerning other deferred credits. For any deferred credit being amortized, show the period of amortization. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
			DEBITS
Line No.	Description and Other Deferred Credits (a)	Balance at Beginning of Year (b)	Contra Account (c)	Amount (d)	Credits (e)	Balance at End of Year (f)
1	(a) Initial payments - contracts	3,940,593	454			3,940,593
2	(b) Deferred rents	2,796	931	2,796
3	Long-term contracting services	633,644	415			633,644
4	Long-term renewable energy contracts	106,257,640	182.3	65,007,343	61,329,106	102,579,403
5	Funds for Utility Job Training Program (FEJA)	10,000,000	557			10,000,000
6	Other	574,536	(c) Various	37,324,956	36,926,622	972,870
47	TOTAL	120,260,137		102,335,095	98,255,728	116,180,770

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: DescriptionOfOtherDeferredCredits


This item includes two contracts, with amortization periods starting April 1, 2000, and May 1, 2000, and continuing through March 31, 2030, and April 30, 2030, respectively.

(b) Concept: DescriptionOfOtherDeferredCredits


This item includes rents for various buildings, with amortization periods ranging from January 1, 1993 to December 31, 2023.


Other deferred credits are offset in Accounts 242, 454, 531, and 923.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)

Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property.
For other (Specify),include deferrals relating to other income and deductions.
Use footnotes as required.

CHANGES DURING YEAR

ADJUSTMENTS

Debits

Credits

Line No.

Account

(a)

Balance at Beginning of Year

(b)

Amounts Debited to Account 410.1

(c)

Amounts Credited to Account 411.1

(d)

Amounts Debited to Account 410.2

(e)

Amounts Credited to Account 411.2

(f)

Account Credited

(g)

Amount

(h)

Account Debited

(i)

Amount

(j)

Balance at End of Year

(k)

Accelerated Amortization (Account 281)

Electric

Defense Facilities

Pollution Control Facilities

Other

5.1

Other (provide details in footnote):

TOTAL Electric (Enter Total of lines 3 thru 7)

Gas

Defense Facilities

Pollution Control Facilities

Other

12.1

Other (provide details in footnote):

TOTAL Gas (Enter Total of lines 10 thru 14)

Other

16.1

Other

16.2

Other

TOTAL (Acct 281) (Total of 8, 15 and 16)

Classification of TOTAL

Federal Income Tax

State Income Tax

Local Income Tax

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization. For other (Specify),include deferrals relating to other income and deductions. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 282
2	Electric	4,971,124,063	184,170,242	322,898,753			254, 410, 411	4,982,461	254, 410, 411	213,881,637	5,041,294,728
3	Gas
4	Other (Specify)
5	Total (Total of lines 2 thru 4)	4,971,124,063	184,170,242	322,898,753				4,982,461		213,881,637	(a) 5,041,294,728
6
7
8
9	TOTAL Account 282 (Total of Lines 5 thru 8)	4,971,124,063	184,170,242	322,898,753				4,982,461		213,881,637	5,041,294,728
10	Classification of TOTAL
11	Federal Income Tax	3,410,008,455	106,092,060	286,186,005					254, 410, 411	213,881,637	3,443,796,147
12	State Income Tax	1,561,115,608	78,078,182	36,712,748			254, 410, 411	4,982,461			1,597,498,581
13	Local Income Tax

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxesOtherProperty


Description:	Beginning Balance		Ending Balance
AFUDC Equity	$	63,954,946	$	72,580,462
CIAC	(156,724,498)		(178,692,699)
Plant Deferred Taxes - FAS 109	5,063,893,615		5,147,406,965
Total	$	4,971,124,063	$	5,041,294,728

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283. For other (Specify),include deferrals relating to other income and deductions. Provide in the space below explanations for Page 276. Include amounts relating to insignificant items listed under Other. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 283
2	Electric
3		1,346,374,129	192,681,241	126,952,710					190, 236, 254	3,676,408	1,415,779,068
9	TOTAL Electric (Total of lines 3 thru 8)	1,346,374,129	192,681,241	126,952,710						3,676,408	1,415,779,068
10	Gas
11
12
13
14
15
16
17	TOTAL Gas (Total of lines 11 thru 16)
18	TOTAL Other
19	TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)	1,346,374,129	192,681,241	126,952,710						3,676,408	(a) 1,415,779,068
20	Classification of TOTAL
21	Federal Income Tax	897,661,489	128,447,140	84,624,276					190, 236, 254	2,451,153	943,935,506
22	State Income Tax	448,712,640	64,234,101	42,328,434					190, 236, 254	1,225,255	471,843,562
23	Local Income Tax
NOTES

FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxesOther


Description	Beginning Balance		Ending Balance
Pension Asset	$	347,053,474	$	385,308,540
Regulatory Asset	969,087,038		992,037,219
Unamortized Loss on Required Debt	4,681,661		4,230,035
Other	25,551,956		34,203,274
Total	$	1,346,374,129	$	1,415,779,068

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

OTHER REGULATORY LIABILITIES (Account 254)
Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Liabilities being amortized, show period of amortization.
			DEBITS
Line No.	Description and Purpose of Other Regulatory Liabilities (a)	Balance at Beginning of Current Quarter/Year (b)	Account Credited (c)	Amount (d)	Credits (e)	Balance at End of Current Quarter/Year (f)
1	(a) Decommissioning the Regulatory Agreement Units	2,954,412,181			825,254,983	3,779,667,164
2	Purchased Electricity - Over Recovery	73,252	555	88,505,990	100,261,131	11,828,393
3	Deferred Income Taxes	2,177,670,710	282, 283, 410, 411	293,012,692	6,593,399	1,891,251,417
4	Transmission Costs - Over Recovery	14,000,739	456.1	50,000,002	35,999,263
5	Renewable Portfolio Standard Costs - Rider REA	1,033,110,493			263,109,920	1,296,220,413
6	Renewable Portfolio Standard Costs - ACP Funds	69,057,169			3,796,928	72,854,097
7	Purchased Electricity - FERC 494 Refund	4,306,304	561.8	4,804,274	497,970
8	Coal to Solar	912,324			10,016	922,340
41	TOTAL	6,253,543,172		436,322,958	1,235,523,610	7,052,743,824

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Line Item

Rate Order Docket Number Or Recovery Mechanism

Amortization Period

Decommissioning the Regulatory Agreement Units

ICC Docket 00-0361

N/A

Purchased Electricity - Over Recovery

ICC Docket No. 05-0159 & 18-1824

4 months from period end

Deferred Income Taxes

ICC Order 18-0034 / FERC Order ER19-5 dated 4/26/2019

Over the life of related assets

Transmission Costs - Over Recovery

FERC Docket ER07-583

12 months from each June

Renewable Portfolio Standard Costs - Rider REA

FEJA

9 months from each September

Renewable Portfolio Standard Costs - ACP Funds

IPA LTRRP approved by ICC

As approved by the IPA & ICC

Purchased Electricity - FERC 494 Refund

FERC Order Docket No. EL05-121-009

Amortization complete as of 12/31/2024 based on settlement amounts which were processed through PJM

Coal to Solar

CEJA

12 months from each October

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

Electric Operating Revenues
The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages. Report below operating revenues for each prescribed account, and manufactured gas revenues in total. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.) See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.	Title of Account (a)	Operating Revenues Year to Date Quarterly/Annual (b)	Operating Revenues Previous year (no Quarterly) (c)	MEGAWATT HOURS SOLD Year to Date Quarterly/Annual (d)	MEGAWATT HOURS SOLD Amount Previous year (no Quarterly) (e)	AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly) (f)	AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly) (g)
1	SalesOfElectricityHeadingAbstract Sales of Electricity
2	ResidentialSalesAbstract (440) Residential Sales	3,734,733,091	3,862,275,761	27,273,825	26,022,565	3,727,675	3,732,459
3	CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales
4	CommercialSalesAbstract Small (or Comm.) (See Instr. 4)	2,217,249,637	2,027,198,786	28,366,580	28,705,593	395,314	391,406
5	IndustrialSalesAbstract Large (or Ind.) (See Instr. 4)	1,107,159,699	896,098,046	27,869,630	26,707,834	2,051	1,875
6	PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting	43,735,834	45,348,653	444,828	454,308	5,707	4,796
7	OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities
8	SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways	14,504,101	12,241,981	376,332	399,921	2	2
9	InterdepartmentalSalesAbstract (448) Interdepartmental Sales
10	SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers	7,117,382,362	6,843,163,227	(f)(g) 84,331,195	(h) 82,290,221	4,130,749	4,130,538
11	SalesForResaleAbstract (447) Sales for Resale	20,927,736	27,394,838	791,465	988,910
12	SalesOfElectricityAbstract TOTAL Sales of Electricity	7,138,310,098	6,870,558,065	85,122,660	83,279,131	4,130,749	4,130,538
13	ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds
14	RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds	7,138,310,098	6,870,558,065	85,122,660	83,279,131	4,130,749	4,130,538
15	OtherOperatingRevenuesAbstract Other Operating Revenues
16	ForfeitedDiscounts (450) Forfeited Discounts	14,347,873	28,067,219
17	MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues	(a) 19,000,296	(d) 19,161,315
18	SalesOfWaterAndWaterPower (453) Sales of Water and Water Power
19	RentFromElectricProperty (454) Rent from Electric Property	95,390,314	87,133,133
20	InterdepartmentalRents (455) Interdepartmental Rents
21	OtherElectricRevenue (456) Other Electric Revenues	(b) 12,770,917	(e) 10,583,695
22	RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others	909,707,286	831,947,358
23	RegionalTransmissionServiceRevenues (457.1) Regional Control Service Revenues
24	MiscellaneousRevenue (457.2) Miscellaneous Revenues
25	OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues
26	OtherOperatingRevenues TOTAL Other Operating Revenues	1,025,674,852	976,892,720
27	ElectricOperatingRevenues TOTAL Electric Operating Revenues	(c) 8,163,984,950	7,847,450,785
Line12, column (b) includes $ 451,537,510 of unbilled revenues.
Line12, column (d) includes 220,388 MWH relating to unbilled revenues

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: MiscellaneousServiceRevenues



Account 451 (Miscellaneous Service Revenues) details are required by Page 300, Instruction No. 5
	For the Years Ended December 31,
	2024		2023
Meter Tampering	$	41,247	$	250,454
Temporary Service Revenues	2,787,669		3,905,485
Electric Choice & Other Data Service Fees	1,772		27,612
Turn On Charge	351,422		994,596
Returned Check Fees	1,400,790		1,390,351
Call Center Referral Services	(83,550)		114,569
Deferred Payment Agreement Reinstatement Fees	1,343,896		2,540,168
Energy Marketplace Services	120,210		209,095
Interconnection Application & Facility Study Fees	10,976,359		8,514,928
AMI Metering Opt-out Fees	995,443		1,061,222
Other	1,065,038		152,835
Total	$	19,000,296	$	19,161,315

(b) Concept: OtherElectricRevenue


Account 456 (Other Electric Revenues) details are required by Page 300, Instruction No. 5
	For the Years Ended December 31,
	2024		2023
Contracting & Engineering Study Services	$	1,067,073	$	9,794,273
IPP Electric Generation Studies reimbursements	6,546,931		517,586
Beneficial Electrification Incentives	(21,253,203)		(654,750)
Affiliate meter and other equipment rentals	15,909		12,611

Affiliate maintenance revenues	852,373		913,975


Total	$	(12,770,917)	$	10,583,695


Total Electric Operating Revenues include the following amounts included in ComEd's 2024 revenue balancing reconciliation:
Total Delivery Service Operating Revenue	$	3,496,179,688

Total Electric Operating Revenues include the following amounts included in ComEd's 2024 energy efficiency formula rate reconciliation:

Total Energy Efficiency Operating Revenue	$	368,080,000
2024 Estimated Reconciliation Recorded as of December 31, 2024	19,064,000		*

* Amount included in Total Energy Efficiency Operating Revenue reported above

Total Electric Operating Revenues include the following amounts included in ComEd's 2024 distributed generation rebate formula rate reconciliation:

Total Distributed Generation Rebate Operating Revenue	$	22,985,000
2024 Estimated Reconciliation Recorded as of December 31, 2024	3,196,000		*

* Amount included in Total Distributed Generation Rebate Operating Revenue reported above

(d) Concept: MiscellaneousServiceRevenues



Refer to the footnote for Line No. 17, column b.

(e) Concept: OtherElectricRevenue


Refer to the footnote for Line No. 21, column b.

(f) Concept: MegawattHoursSoldSalesToUltimateConsumers


	MWh's for the Years Ended December 31,
	2024		2023
Retail deliveries for Full Service	$	30,116,920	$	29,964,172
Retail deliveries for Delivery Only	54,214,275		52,326,049
Total retail deliveries	$	84,331,195	$	82,290,221

General Notes:
Full Service reflects deliveries to customers taking electric service under tariff rates. Delivery Only service reflects customers electing to receive electricity from Alternative Retail Electric Suppliers.

(g) Concept: MegawattHoursSoldSalesToUltimateConsumers


Retail deliveries for Full Service	$	30,116,920
Retail deliveries for Delivery Only	54,214,275
Total Sales to Ultimate Customers	$	84,331,195

Refer to the footnote on Page 300, line No. 10, Column (d) for additional details.

(h) Concept: MegawattHoursSoldSalesToUltimateConsumers



Refer to the footnote for Line No. 10, column d.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.	Description of Service (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46	TOTAL

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	(a) BES - Residential	19,260,037	3,061,021,577	2,879,773	6,688	0.1589
2	BES - Residential Space Heating	1,202,387	185,040,605	43,562	27,602	0.1539
3	BES H - Hourly	419,707	58,614,659	975	430,469	0.1397
4	(b) BES - Outdoor Lighting	4,941	1,049,836	2,016	2,451	0.2125
5	RDS - Delivery Service	6,406,826	604,054,430	805,381	7,955	0.0943
41	TOTAL Billed Residential Sales	27,293,898	3,909,781,107	3,727,675	7,322	0.1432
42	TOTAL Unbilled Rev. (See Instr. 6)	20,073	175,048,016			8.7206
43	TOTAL	27,273,825	3,734,733,091	3,727,675	7,317	0.1369

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: DescriptionOfNumberAndTitleOfRateSchedule


The following legend is applicable for the various rates shown in column (a) -
BES is Basic Electric Service
RDS is Retail Delivery Service

(b) Concept: DescriptionOfNumberAndTitleOfRateSchedule

Each class of customers may have multiple billing rates, a primary rate, and for certain customers, an Outdoor Lighting rate. In order to appropriately calculate the amount presented in Column (e) on Page 304, these customers are reported in each class separately for Page 304. However, for purposes of page 300-301, Column (f), the customers are reported only once. This footnote applies to all BES - Outdoor Lighting lines shown in Column (a).

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	BES - Fixed	4,628,899	706,542,407	220,014	21,039	0.1526
2	BES H - Hourly	3,314,505	344,890,014	8,501	389,896	0.1041
3	BES - Outdoor Lighting	23,012	3,087,128	525	43,832	0.1342
4	RDS - Delivery Service	20,468,387	1,309,704,348	166,274	123,100	0.0640
41	TOTAL Billed Small or Commercial	28,434,803	2,364,223,897	395,314	71,930	0.0831
42	TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)	68,223	146,974,260			2.1543
43	TOTAL Small or Commercial	28,366,580	2,217,249,637	395,314	71,757	0.0782

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	BES - Fixed	8,643	891,355	15	576,200	0.1031
2	BES H - Hourly	1,634,293	127,544,044	161	10,150,888	0.0780
3	BES - Outdoor Lighting	162	5,457	94	1,723	0.0337
4	RDS - Delivery Service	25,870,368	1,101,947,948	1,781	14,525,754	0.0426
41	TOTAL Billed Large (or Ind.) Sales	27,513,466	1,230,377,890	2,051	13,414,659	0.0447
42	TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)	356,164	123,218,191			0.3460
43	TOTAL Large (or Ind.)	27,869,630	1,107,159,699	2,051	13,588,313	0.0397

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	BES H - Hourly	70,895	12,401,889	926	76,560	0.1749
2	BES - Outdoor Lighting	40,255	8,931,286	3,231	12,459	0.2219
3	RDS - Delivery Service	334,631	25,075,194	1,550	215,891	0.0749
41	TOTAL Billed Public Street and Highway Lighting	445,781	46,408,369	5,707	78,111	0.1041
42	TOTAL Unbilled Rev. (See Instr. 6)	953	2,672,535			2.8043
43	TOTAL	444,828	43,735,834	5,707	77,944	0.0983

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	RDS - railroads	422,859	18,128,609	2	211,429,500	0.0429
41	TOTAL Billed Sales To Railroads and Railways	422,859	18,128,609	2	211,429,500	0.0429
42	TOTAL Unbilled Rev. (See Instr. 6)	46,527	3,624,508			0.0779
43	TOTAL	376,332	14,504,101	2	188,166,000	0.0385

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
41	TOTAL Billed - All Accounts	84,110,807	7,568,919,872	4,130,749	20,362	0.0900
42	TOTAL Unbilled Rev. (See Instr. 6) - All Accounts	220,388	451,537,510			2.0488
43	TOTAL - All Accounts	(a) 84,331,195	7,117,382,362	4,130,749	20,415	0.0844

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: MegawattHoursOfElectricitySoldByRateSchedulesIncludingUnbilledRevenue


	MWh's for the Years Ended December 31,
	2024	2023
Retail Deliveries for Full Service	30,116,920	29,964,172
Retail Deliveries for Delivery Only	54,214,275	52,326,049
Total Retail Deliveries	84,331,195	82,290,221

General Notes: Full Service reflects deliveries to customers taking electric service under tariff rates. Delivery Only service reflects customers electing to receive electricity from a competitive electric generation supplier.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

SALES FOR RESALE (Account 447)
Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326). Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k). In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24. Footnote entries as required and provide explanations following all required data.
					ACTUAL DEMAND (MW)			REVENUE
Line No.	Name of Company or Public Authority (Footnote Affiliations) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Average Monthly Billing Demand (MW) (d)	Average Monthly NCP Demand (e)	Average Monthly CP Demand (f)	Megawatt Hours Sold (g)	Demand Charges ($) (h)	Energy Charges ($) (i)	Other Charges ($) (j)	Total ($) (h+i+j) (k)
1	Requirement Sales:
2	Non-Requirement Sales:
3	(a) PJM Interconnection, LLC	OS	PJM-1				791,465		20,927,736		20,927,736
15	Subtotal - RQ
16	Subtotal-Non-RQ						791,465		20,927,736		20,927,736
17	Total						791,465		20,927,736		20,927,736

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityReceivingElectricityPurchasedForResale


The MegaWatt Hours Sold and the associated Revenue Energy Charges reflect spot market sales.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

ELECTRIC OPERATION AND MAINTENANCE EXPENSES
If the amount for previous year is not derived from previously reported figures, explain in footnote.
Line No.	Account (a)	Amount for Current Year (b)	Amount for Previous Year (c) (c)
1	PowerProductionExpensesAbstract 1. POWER PRODUCTION EXPENSES
2	SteamPowerGenerationAbstract A. Steam Power Generation
3	SteamPowerGenerationOperationAbstract Operation
4	OperationSupervisionAndEngineeringSteamPowerGeneration (500) Operation Supervision and Engineering
5	FuelSteamPowerGeneration (501) Fuel
6	SteamExpensesSteamPowerGeneration (502) Steam Expenses
7	SteamFromOtherSources (503) Steam from Other Sources
8	SteamTransferredCredit (Less) (504) Steam Transferred-Cr.
9	ElectricExpensesSteamPowerGeneration (505) Electric Expenses
10	MiscellaneousSteamPowerExpenses (506) Miscellaneous Steam Power Expenses
11	RentsSteamPowerGeneration (507) Rents
12	Allowances (509) Allowances
13	SteamPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 4 thru 12)
14	SteamPowerGenerationMaintenanceAbstract Maintenance
15	MaintenanceSupervisionAndEngineeringSteamPowerGeneration (510) Maintenance Supervision and Engineering
16	MaintenanceOfStructuresSteamPowerGeneration (511) Maintenance of Structures
17	MaintenanceOfBoilerPlantSteamPowerGeneration (512) Maintenance of Boiler Plant
18	MaintenanceOfElectricPlantSteamPowerGeneration (513) Maintenance of Electric Plant
19	MaintenanceOfMiscellaneousSteamPlant (514) Maintenance of Miscellaneous Steam Plant
20	SteamPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 15 thru 19)
21	PowerProductionExpensesSteamPower TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)
22	NuclearPowerGenerationAbstract B. Nuclear Power Generation
23	NuclearPowerGenerationOperationAbstract Operation
24	OperationSupervisionAndEngineeringNuclearPowerGeneration (517) Operation Supervision and Engineering
25	NuclearFuelExpense (518) Fuel
26	CoolantsAndWater (519) Coolants and Water
27	SteamExpensesNuclearPowerGeneration (520) Steam Expenses
28	SteamFromOtherSourcesNuclearPowerGeneration (521) Steam from Other Sources
29	SteamTransferredCreditNuclearPowerGeneration (Less) (522) Steam Transferred-Cr.
30	ElectricExpensesNuclearPowerGeneration (523) Electric Expenses
31	MiscellaneousNuclearPowerExpenses (524) Miscellaneous Nuclear Power Expenses
32	RentsNuclearPowerGeneration (525) Rents
33	NuclearPowerGenerationOperationsExpense TOTAL Operation (Enter Total of lines 24 thru 32)
34	NuclearPowerGenerationMaintenanceAbstract Maintenance
35	MaintenanceSupervisionAndEngineeringNuclearPowerGeneration (528) Maintenance Supervision and Engineering
36	MaintenanceOfStructuresNuclearPowerGeneration (529) Maintenance of Structures
37	MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration (530) Maintenance of Reactor Plant Equipment
38	MaintenanceOfElectricPlantNuclearPowerGeneration (531) Maintenance of Electric Plant
39	MaintenanceOfMiscellaneousNuclearPlant (532) Maintenance of Miscellaneous Nuclear Plant
40	NuclearPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 35 thru 39)
41	PowerProductionExpensesNuclearPower TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)
42	HydraulicPowerGenerationAbstract C. Hydraulic Power Generation
43	HydraulicPowerGenerationOperationAbstract Operation
44	OperationSupervisionAndEngineeringHydraulicPowerGeneration (535) Operation Supervision and Engineering
45	WaterForPower (536) Water for Power
46	HydraulicExpenses (537) Hydraulic Expenses
47	ElectricExpensesHydraulicPowerGeneration (538) Electric Expenses
48	MiscellaneousHydraulicPowerGenerationExpenses (539) Miscellaneous Hydraulic Power Generation Expenses
49	RentsHydraulicPowerGeneration (540) Rents
50	HydraulicPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 44 thru 49)
51	HydraulicPowerGenerationContinuedAbstract C. Hydraulic Power Generation (Continued)
52	HydraulicPowerGenerationMaintenanceAbstract Maintenance
53	MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration (541) Mainentance Supervision and Engineering
54	MaintenanceOfStructuresHydraulicPowerGeneration (542) Maintenance of Structures
55	MaintenanceOfReservoirsDamsAndWaterways (543) Maintenance of Reservoirs, Dams, and Waterways
56	MaintenanceOfElectricPlantHydraulicPowerGeneration (544) Maintenance of Electric Plant
57	MaintenanceOfMiscellaneousHydraulicPlant (545) Maintenance of Miscellaneous Hydraulic Plant
58	HydraulicPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 53 thru 57)
59	PowerProductionExpensesHydraulicPower TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
60	OtherPowerGenerationAbstract D. Other Power Generation
61	OtherPowerGenerationOperationAbstract Operation
62	OperationSupervisionAndEngineeringOtherPowerGeneration (546) Operation Supervision and Engineering
63	Fuel (547) Fuel
64	GenerationExpenses (548) Generation Expenses
64.1	OperationOfEnergyStorageEquipment (548.1) Operation of Energy Storage Equipment
65	MiscellaneousOtherPowerGenerationExpenses (549) Miscellaneous Other Power Generation Expenses
66	RentsOtherPowerGeneration (550) Rents
67	OtherPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 62 thru 67)
68	OtherPowerGenerationMaintenanceAbstract Maintenance
69	MaintenanceSupervisionAndEngineeringOtherPowerGeneration (551) Maintenance Supervision and Engineering
70	MaintenanceOfStructures (552) Maintenance of Structures
71	MaintenanceOfGeneratingAndElectricPlant (553) Maintenance of Generating and Electric Plant
71.1	MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration (553.1) Maintenance of Energy Storage Equipment
72	MaintenanceOfMiscellaneousOtherPowerGenerationPlant (554) Maintenance of Miscellaneous Other Power Generation Plant
73	OtherPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 69 thru 72)
74	PowerProductionExpensesOtherPower TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)
75	OtherPowerSuplyExpensesAbstract E. Other Power Supply Expenses
76	PurchasedPower (555) Purchased Power	1,381,297,380	1,742,592,887
76.1	PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations
77	SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching
78	OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses	1,259,660,722	701,205,113
79	OtherPowerSupplyExpense TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)	2,640,958,102	2,443,798,000
80	PowerProductionExpenses TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)	2,640,958,102	2,443,798,000
81	TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES
82	TransmissionExpensesOperationAbstract Operation
83	OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering	29,451,209	26,886,530
85	LoadDispatchReliability (561.1) Load Dispatch-Reliability
86	LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System
87	LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling
88	SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services	415,402,822	397,423,917
89	ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development
90	TransmissionServiceStudies (561.6) Transmission Service Studies	43,485	24,238
91	GenerationInterconnectionStudies (561.7) Generation Interconnection Studies	4,200,898	357,679
92	ReliabilityPlanningAndStandardsDevelopmentServices (561.8) Reliability, Planning and Standards Development Services	22,092,777	15,259,248
93	StationExpensesTransmissionExpense (562) Station Expenses	3,671,290	2,597,339
93.1	OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment
94	OverheadLineExpense (563) Overhead Lines Expenses	360,000	390,000
95	UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses	631,724	324,074
96	TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others	10,271,201	10,659,454
97	MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses	(a) 28,182,513	(c) 25,596,876
98	RentsTransmissionElectricExpense (567) Rents	1,384,952	1,428,087
99	TransmissionOperationExpense TOTAL Operation (Enter Total of Lines 83 thru 98)	514,972,871	480,167,442
100	TransmissionMaintenanceAbstract Maintenance
101	MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering	1,341,025	1,463,052
102	MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures	650,421	1,397,640
103	MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware	524,678	299,080
104	MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software	2,843,886	1,804,347
105	MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment	1,092,473	495,512
106	MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant
107	MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment	32,320,746	24,010,672
107.1	MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment
108	MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines	28,160,597	25,958,394
109	MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines	1,114,946	2,067,106
110	MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant	596,199	8,959,648
111	TransmissionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 101 thru 110)	66,415,079	66,455,451
112	TransmissionExpenses TOTAL Transmission Expenses (Total of Lines 99 and 111)	581,387,950	546,622,893
113	RegionalMarketExpensesAbstract 3. REGIONAL MARKET EXPENSES
114	RegionalMarketExpensesOperationAbstract Operation
115	OperationSupervision (575.1) Operation Supervision
116	DayAheadAndRealTimeMarketAdministration (575.2) Day-Ahead and Real-Time Market Facilitation
117	TransmissionRightsMarketAdministration (575.3) Transmission Rights Market Facilitation
118	CapacityMarketAdministration (575.4) Capacity Market Facilitation
119	AncillaryServicesMarketAdministration (575.5) Ancillary Services Market Facilitation
120	MarketMonitoringAndCompliance (575.6) Market Monitoring and Compliance
121	MarketFacilitationMonitoringAndComplianceServices (575.7) Market Facilitation, Monitoring and Compliance Services	8,464,510	6,841,512
122	RentsRegionalMarketExpenses (575.8) Rents
123	RegionalMarketOperationExpense Total Operation (Lines 115 thru 122)	8,464,510	6,841,512
124	RegionalMarketExpensesMaintenanceAbstract Maintenance
125	MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses (576.1) Maintenance of Structures and Improvements
126	MaintenanceOfComputerHardware (576.2) Maintenance of Computer Hardware
127	MaintenanceOfComputerSoftware (576.3) Maintenance of Computer Software
128	MaintenanceOfCommunicationEquipmentRegionalMarketExpenses (576.4) Maintenance of Communication Equipment
129	MaintenanceOfMiscellaneousMarketOperationPlant (576.5) Maintenance of Miscellaneous Market Operation Plant
130	RegionalMarketMaintenanceExpense Total Maintenance (Lines 125 thru 129)
131	RegionalMarketExpenses TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)	8,464,510	6,841,512
132	DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES
133	DistributionExpensesOperationAbstract Operation
134	OperationSupervisionAndEngineeringDistributionExpense (580) Operation Supervision and Engineering	21,599,243	26,273,230
135	LoadDispatching (581) Load Dispatching	72,200	81,592
136	StationExpensesDistribution (582) Station Expenses	1,769,922	1,367,288
137	OverheadLineExpenses (583) Overhead Line Expenses	7,813,568	3,090,935
138	UndergroundLineExpenses (584) Underground Line Expenses	22,845,719	20,013,201
138.1	OperationOfEnergyStorageEquipmentDistribution (584.1) Operation of Energy Storage Equipment
139	StreetLightingAndSignalSystemExpenses (585) Street Lighting and Signal System Expenses	3,337,620	2,328,703
140	MeterExpenses (586) Meter Expenses	8,107,173	9,988,294
141	CustomerInstallationsExpenses (587) Customer Installations Expenses	26,897,270	18,598,507
142	MiscellaneousDistributionExpenses (588) Miscellaneous Expenses	123,860,210	106,833,329
143	RentsDistributionExpense (589) Rents	5,284,113	4,283,656
144	DistributionOperationExpensesElectric TOTAL Operation (Enter Total of Lines 134 thru 143)	221,587,038	192,858,735
145	DistributionExpensesMaintenanceAbstract Maintenance
146	MaintenanceSupervisionAndEngineering (590) Maintenance Supervision and Engineering	6,255,990	6,584,314
147	MaintenanceOfStructuresDistributionExpense (591) Maintenance of Structures	2,282,694	2,043,511
148	MaintenanceOfStationEquipment (592) Maintenance of Station Equipment	52,392,033	43,855,527
148.1	MaintenanceOfEnergyStorageEquipment (592.2) Maintenance of Energy Storage Equipment
149	MaintenanceOfOverheadLines (593) Maintenance of Overhead Lines	237,697,241	223,450,528
150	MaintenanceOfUndergroundLines (594) Maintenance of Underground Lines	67,546,728	55,416,786
151	MaintenanceOfLineTransformers (595) Maintenance of Line Transformers	6,093,218	6,818,851
152	MaintenanceOfStreetLightingAndSignalSystems (596) Maintenance of Street Lighting and Signal Systems	2,211,780	2,433,605
153	MaintenanceOfMeters (597) Maintenance of Meters	1,669,096	1,167,490
154	MaintenanceOfMiscellaneousDistributionPlant (598) Maintenance of Miscellaneous Distribution Plant	10,421,514	9,962,073
155	DistributionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 146 thru 154)	383,232,102	351,732,685
156	DistributionExpenses TOTAL Distribution Expenses (Total of Lines 144 and 155)	604,819,140	544,591,420
157	CustomerAccountsExpensesAbstract 5. CUSTOMER ACCOUNTS EXPENSES
158	CustomerAccountsExpensesOperationsAbstract Operation
159	SupervisionCustomerAccountExpenses (901) Supervision	276,146	336,289
160	MeterReadingExpenses (902) Meter Reading Expenses	16,223,048	16,440,582
161	CustomerRecordsAndCollectionExpenses (903) Customer Records and Collection Expenses	214,977,707	197,074,440
162	UncollectibleAccounts (904) Uncollectible Accounts	70,648,877	44,780,156
163	MiscellaneousCustomerAccountsExpenses (905) Miscellaneous Customer Accounts Expenses
164	CustomerAccountExpenses TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)	302,125,778	258,631,467
165	CustomerServiceAndInformationalExpensesAbstract 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166	CustomerServiceAndInformationalExpensesOperationAbstract Operation
167	SupervisionCustomerServiceAndInformationExpenses (907) Supervision
168	CustomerAssistanceExpenses (908) Customer Assistance Expenses	56,792,244	37,985,667
169	InformationalAndInstructionalAdvertisingExpenses (909) Informational and Instructional Expenses	10,904,114	12,655,336
170	MiscellaneousCustomerServiceAndInformationalExpenses (910) Miscellaneous Customer Service and Informational Expenses
171	CustomerServiceAndInformationExpenses TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)	67,696,358	50,641,003
172	SalesExpenseAbstract 7. SALES EXPENSES
173	SalesExpenseOperationAbstract Operation
174	SupervisionSalesExpense (911) Supervision
175	DemonstratingAndSellingExpenses (912) Demonstrating and Selling Expenses
176	AdvertisingExpenses (913) Advertising Expenses
177	MiscellaneousSalesExpenses (916) Miscellaneous Sales Expenses
178	SalesExpenses TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)
179	AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
180	AdministrativeAndGeneralExpensesOperationAbstract Operation
181	AdministrativeAndGeneralSalaries (920) Administrative and General Salaries	63,144,769	54,461,993
182	OfficeSuppliesAndExpenses (921) Office Supplies and Expenses	26,068,215	24,072,201
183	AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit	72,257,203	55,017,767
184	OutsideServicesEmployed (923) Outside Services Employed	290,621,265	247,635,892
185	PropertyInsurance (924) Property Insurance	2,301,581	2,272,568
186	InjuriesAndDamages (925) Injuries and Damages	32,482,933	20,785,264
187	EmployeePensionsAndBenefits (926) Employee Pensions and Benefits	111,874,535	74,976,530
188	FranchiseRequirements (927) Franchise Requirements	42,867,222	37,509,540
189	RegulatoryCommissionExpenses (928) Regulatory Commission Expenses	7,763,185	9,224,259
190	DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr.	42,867,222	37,509,540
191	GeneralAdvertisingExpenses (930.1) General Advertising Expenses	3,531,084	8,455,675
192	MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses	11,894,831	10,424,781
193	RentsAdministrativeAndGeneralExpense (931) Rents	1,193,352	2,721,104
194	AdministrativeAndGeneralOperationExpense TOTAL Operation (Enter Total of Lines 181 thru 193)	478,618,547	400,012,500
195	AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance
196	MaintenanceOfGeneralPlant (935) Maintenance of General Plant	43,253,140	41,192,422
197	AdministrativeAndGeneralExpenses TOTAL Administrative & General Expenses (Total of Lines 194 and 196)	521,871,687	441,204,922
198	OperationsAndMaintenanceExpensesElectric TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)	(b) 4,727,323,525	(d) 4,292,331,217

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: MiscellaneousTransmissionExpenses


Included in Account 566 (Miscellaneous Transmission Expense) are expenses (benefits) associated with the following:
	For the Years Ended December 31,
	2024		2023
PJM Interconnection, LLC (PJM) Related Activity:
PJM Transmission benefit	$	—	$	—

Other	(1,860,693)		(1,318,398)
Sub-total (PJM related activity)	$	(1,860,693)	$	(1,318,398)
Other Miscellaneous transmission expenses	30,043,206		26,915,274
Total for Account 566	$	28,182,513	$	25,596,876

Expenses associated with PJM were recorded in the following accounts:
	For the Years Ended December 31,
	2024		2023
Account 555	$	751,593,712	$	691,537,366
Account 561.4	415,402,822		397,423,917
Account 561.8	22,092,777		15,259,248
Account 566	(1,860,693)		(1,318,398)
Account 575.7	8,464,510		6,841,513
Total	$	1,195,693,128	$	1,109,743,646

(b) Concept: OperationsAndMaintenanceExpensesElectric


Includes expenses for the year 2023 related to the following:
Postretirement benefit expenses, other than pension expenses (PBOP), of ($6,219,944)
Power procurement expenses of $326,428 in A&G accounts 920-935.


Refer to the footnote for Line No. 97, Column (b).

(d) Concept: OperationsAndMaintenanceExpensesElectric


Includes expenses for the year 2023 related to the following:
Postretirement benefit expenses, other than pension expenses (PBOP), of ($5,587,089)
Power procurement expenses of $295,182 in A&G accounts 920-935.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

PURCHASED POWER (Account 555)
Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatthours shown on bills rendered to the respondent, excluding purchases for energy storage. Report in column (h) the megawatthours shown on bills rendered to the respondent for energy storage purchases. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. The data in columns (g) through (n) must be totaled on the last line of the schedule. The total amount in columns (g) and (h) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13. Footnote entries as required and provide explanations following all required data.
					Actual Demand (MW)				POWER EXCHANGES		COST/SETTLEMENT OF POWER
Line No.	NameOfCompanyOrPublicAuthorityProvidingPurchasedPower Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	RateScheduleTariffNumber Ferc Rate Schedule or Tariff Number (c)	AverageMonthlyBillingDemand Average Monthly Billing Demand (MW) (d)	AverageMonthlyNonCoincidentPeakDemand Average Monthly NCP Demand (e)	AverageMonthlyCoincidentPeakDemand Average Monthly CP Demand (f)	MegawattHoursPurchasedOtherThanStorage MegaWatt Hours Purchased (Excluding for Energy Storage) (g)	MegawattHoursPurchasedForEnergyStorage MegaWatt Hours Purchased for Energy Storage (h)	EnergyReceivedThroughPowerExchanges MegaWatt Hours Received (i)	EnergyDeliveredThroughPowerExchanges MegaWatt Hours Delivered (j)	DemandChargesOfPurchasedPower Demand Charges ($) (k)	EnergyChargesOfPurchasedPower Energy Charges ($) (l)	OtherChargesOfPurchasedPower Other Charges ($) (m)	SettlementOfPower Total (k+l+m) of Settlement ($) (n)
1	(a) AEP Energy Partners, Inc.	OS					224,550					7,279,436		7,279,436
2	Dynegy Marketing ad Trade, LLC	OS					3,462,825					136,046,081		136,046,081
3	Constellation Energy Generation, LLC	OS					1,722,725					76,444,798		76,444,798
4	J. ARON & COMPANY LLC	OS					726,100					40,793,017		40,793,017
5	Macquarie Energy, LLC	OS					454,200					17,584,045		17,584,045
6	Midwest Generation, LLC	OS					107,200					3,002,372		3,002,372
7	Morgan Stanley Capital Group Inc.	OS					1,139,525					45,975,302		45,975,302
8	Mercuria Energy America, LLC	OS					1,210,150					44,970,901		44,970,901
9	NextEra Energy Marketing, LLC	OS					549,675					27,919,029		27,919,029
10	NRG Power Marketing, LLC	OS					576,575					31,037,923		31,037,923
11	Shell Energy North America (US), L.P.	OS					784,400					36,568,060		36,568,060
12	Tidal	OS					473,800					24,509,656		24,509,656
13	TransAlta Energy Marketing (U.S.) Inc.	OS					386,750					21,021,620		21,021,620
14	ConocoPhillips Company	OS					55,225					1,763,898		1,763,898
15	DRW Energy Trading LLC	OS					8,000					279,120		279,120
16	Cogeneration	OS					409,295					42,124,775		42,124,775
17	PJM Interconnection, LLC	OS					20,137,848					751,593,712		751,593,712
18	Deferred Energy Costs	OS											(b) 483,462	483,462
19	Other Net Metering Arrangements	OS					241,866						4,240,057	4,240,057
20	Other Miscellaneous Adjustments	OS											(c) 68,627,040	68,627,040
15	TOTAL						(d) 32,670,709	0	0	0		1,308,913,745	72,383,635	1,381,297,380

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower


This footnote pertains to Column (a) of Pages 326. Refer to Notes to Financial Statements, Page 122-123, for information regarding the Respondent's energy procurement for retail customers pursuant to the ICC-approved procurement process.

(b) Concept: OtherChargesOfPurchasedPower





The Respondent's electricity costs are recoverable or refundable under the Respondent's ICC approved rates. The Respondent recovers or refunds the difference between the actual cost of electricity and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates.


Represents the settlement activity associated with the 20-year floating-to-fixed energy swap contracts entered into on December 17, 2010 with unaffiliated suppliers for the procurement of long-term renewable energy and associated RECs.

(d) Concept: MegawattHoursPurchasedOtherThanStorage


Reflects utility zone load, which includes the following amounts purchased by ComEd to serve its Full Service customers.

	1Q 2024 Month	MWhs
	January	3,003,195
	February	2,483,577
	March	2,346,099
	Quarter Total	7,832,871

	2Q 2024 Month	MWhs
	April	1,965,250
	May	2,281,136
	June	3,353,019
	Quarter Total	7,599,405

	3Q 2024 Month	MWhs
	July	3,436,174
	August	3,380,589
	September	2,969,571
	Quarter Total	9,786,334

	4Q 2024 Month	MWhs
	October	2,346,387
	November	2,291,127
	December	2,814,585
	Quarter Total	7,452,099

	YTD Total	32,670,709

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")

Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter.
Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c).
Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c).
In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided.
Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract.
Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain.
Report in column (i) and (j) the total megawatthours received and delivered.
In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (0) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively.
Footnote entries and provide explanations following all required data.

TRANSFER OF ENERGY

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS

Line No.

(a)

(b)

(c)

(d)

(e)

(f)

(g)

(h)

(i)

(j)

(k)

(l)

(m)

(n)

PJM Interconnection L.L.C.

FNO

PJM OATT

(a)

479,754,898

PJM Interconnection L.L.C.

FNS

PJM OATT

(b)

402,821,146

PJM Interconnection L.L.C.

PJM OATT

(c)

27,131,242

TOTAL

909,707,286

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers


Network Integration Transmission Service (NITS) for Third Party Suppliers (difference between NITS Credits and Provider of Last Resort Network Integration Charges).

(b) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers


Network Integration Transmission Service (NITS) for Self.


The details of the Other Transmission Services are as follows:
Transmission Owner Scheduling, System Control and Dispatch Service	$	22,533,473
Other Supporting Facilities	4,597,769



	$	27,131,242

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

TRANSMISSION OF ELECTRICITY BY ISO/RTOs
Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a). In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided. In column (d) report the revenue amounts as shown on bills or vouchers. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No.	Payment Received by (Transmission Owner Name) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Total Revenue by Rate Schedule or Tariff (d)	Total Revenue (e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
40	TOTAL

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. Enter ""TOTAL"" in column (a) as the last line. Footnote entries and provide explanations following all required data.
			TRANSFER OF ENERGY		EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.	NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	TransmissionOfElectricityByOthersEnergyReceived MegaWatt Hours Received (c)	TransmissionOfElectricityByOthersEnergyDelivered MegaWatt Hours Delivered (d)	DemandChargesTransmissionOfElectricityByOthers Demand Charges ($) (e)	EnergyChargesTransmissionOfElectricityByOthers Energy Charges ($) (f)	OtherChargesTransmissionOfElectricityByOthers Other Charges ($) (g)	ChargesForTransmissionOfElectricityByOthers Total Cost of Transmission ($) (h)
1	Commonwealth Edison Company of Indiana, Inc.	OS					(a) 10,271,201	10,271,201
	TOTAL		0	0	0	0	10,271,201	10,271,201

FOOTNOTE DATA

(a) Concept: OtherChargesTransmissionOfElectricityByOthers


Commonwealth Edison Company of Indiana, Inc., a 100% owned subsidiary of the Respondent, provides transmission service to the Respondent under a service agreement.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.	Description (a)	Amount (b)
1	IndustryAssociationDues Industry Association Dues	842,152
2	NuclearPowerResearchExpenses Nuclear Power Research Expenses
3	OtherExperimentalAndGeneralResearchExpenses Other Experimental and General Research Expenses
4	PublicationAndDistributionExpensesForSecuritiesToStockholders Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities
5	OtherMiscellaneousGeneralExpenses Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6	Accrued Vacation Pay	3,733,621
7	Environmental remediation expenses	1,163,834
8	Other environmental expenses	36,787
9	Director's fees and expenses	336,177
10	Sale or write-off of materials and supplies	373,660
11	Bank Fees	1,096,750
12	Undistributed employee expenses	198,518
13	Information technology upgrades expenses	894,404
14	Residential Time of Use Pricing Pilot Development and Operation	386,830
15	Smart meter network professional services and other costs	282,759
16	Miscellaneous Adjustments	2,549,339
46	MiscellaneousGeneralExpenses TOTAL	11,894,831

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
Report in section A for the year the amounts for: (b) Depreciation Expense (Account 403); (c) Depreciation Expense for Asset Retirement Costs (Account 403.1); (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405). Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year. Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used. In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used. For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type of mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
	A. Summary of Depreciation and Amortization Charges
Line No.	FunctionalClassificationAxis Functional Classification (a)	DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments Depreciation Expense (Account 403) (b)	DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments Depreciation Expense for Asset Retirement Costs (Account 403.1) (c)	AmortizationOfLimitedTermPlantOrProperty Amortization of Limited Term Electric Plant (Account 404) (d)	AmortizationOfOtherElectricPlant Amortization of Other Electric Plant (Acc 405) (e)	DepreciationAndAmortization Total (f)
1	Intangible Plant			(a) 130,027,166		130,027,166
2	Steam Production Plant
3	Nuclear Production Plant
4	Hydraulic Production Plant-Conventional
5	Hydraulic Production Plant-Pumped Storage
6	Other Production Plant
7	Transmission Plant	171,649,041	203,858	94,329		171,947,228
8	Distribution Plant	754,188,674	1,321,985	197,459		755,708,118
9	Regional Transmission and Market Operation
10	General Plant	126,439,677	304,317	883,668		(b) 125,860,326
11	Common Plant-Electric
12	TOTAL	1,052,277,392	1,830,160	129,435,286		1,183,542,838

B. Basis for Amortization Charges
See footnote data for Page 336, Line No. 1, Column (d) for required information.

	C. Factors Used in Estimating Depreciation Charges
Line No.	AccountNumberFactorsUsedInEstimatingDepreciationCharges Account No. (a)	DepreciablePlantBase Depreciable Plant Base (in Thousands) (b)	UtilityPlantEstimatedAverageServiceLife Estimated Avg. Service Life (c)	UtilityPlantNetSalvageValuePercentage Net Salvage (Percent) (d)	UtilityPlantAppliedDepreciationRate Applied Depr. Rates (Percent) (e)	MortalityCurveType Mortality Curve Type (f)	UtilityPlantWeightedAverageRemainingLife Average Remaining Life (g)
12	(c) Transmission-	6,784,364	63 years	44	(e) 2.53		47 years, 8 months, 50 days
13	Distribution-
14	Excl HVD,Transf&Meters	19,709,820	54 years	46	(f) 2.75		43 years, 3 months, 10 days
15	High Voltage Distribution	4,336,267	59 years	38	(g) 2.5		44 years, 5 months, 14 days
16	Line Transformers	1,687,787	35 years		2.33	SQ	22 years, 3 months, 19 days
17	Non AMI Meters	48	0 years				0 years
18	AMI Meters	806,671	15 years	15	7.87	SQ	9 years, 6 months
19	Meters Other (Relay/CT/PT, etc.)	58,657	35 years	10	3.29	SQ	24 years, 3 months, 19 days
20	General Plant-
21	Structures & Improvements	811,234	50 years	20	2.6	R1	41 years, 6 months
22	Computer Equipment	123,424	5 years		19.99	SQ	2 years, 10 months, 25 days
23	Furniture & Equipment	41,968	15 years		6.67	SQ	9 years, 10 months, 25 days
24	Office Machines	305	10 years		10	SQ	5 years
25	Transportation:
26	Passenger Cars	5,759	8 years	10	10.92	R3	3 years, 10 months, 25 days
27	Tractor Trailers	1,087	15 years	10	1.24	R2.5	3 years, 2 months, 13 days
28	Trailers	25,127	18 years	15	4.41	S0	13 years, 6 months
29	Light-duty Trucks	93,599	10 years	10	7.45	R1.5	6 years
30	Heavy-duty Trucks	378,004	14 years	10	5.86	S1.5	9 years, 2 months, 13 days
31	Stores Equipment	8,264	15 years		6.67	SQ	10 years, 1 month, 5 days
32	Tools, Shop & Garage Equipment	274,307	25 years		4	SQ	14 years, 8 months, 13 days
33	Laboratory Equipment	19,049	15 years		6.67	SQ	11 years, 7 months, 5 days
34	Power Operated Equipment	7,741	15 years	5	6.63	L3	6 years, 7 months, 5 days
35	Communications Equipment	274,047	15 years	10	7.33	SQ	9 years, 4 months, 25 days
36	MESH Communications Equipment	180,039	10 years	10	11	SQ	5 years, 1 month, 5 days
37	SCADA, Fiber, Microwave Comm Equip	833,023	20 years	10	2.27	L2	14 years, 3 months, 19 days
38	Smart Street Lights Comm Equip	44	12 years	10	9.17	SQ	6 years, 6 months
39	(d) Miscellaneous Equipment	19,916	15 years		6.67	SQ	10 years, 8 months, 50 days
40	General Notes

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: AmortizationOfLimitedTermPlantOrProperty

The amortization charges shown in Column (d), Line 1 - Intangible Plant represent the straight-line amortization of the development costs of the following software:

System

Avg Remaining Life in Years

Fusion SW

Common MDM

BIDA Customer Proj

BIDA SESII Enhance

Robotic Process SW

Digital Strgy Epay

EU North Star RE

CIS Transformation

EU Custon Analytic

ISUM 2020 SW

EMS Implementation

BIDA AMI

GIS

EU SW Electric

Grid FR

Misc Comp Software FR

SES

BIDA Grid EOL

Cloud Serv 3 yr

Mobile App

IVR Convergence

EU Dig Prgm: Web

Port Mgmt Tool

SAM SW

UI Plan SW

Cloud Serv 5 yr

*Fully amortized during 2024.

The amortization charges shown in Column (d), Line 1 - Intangible Plant, represent the straight line amortization of the development costs related to software. See note for Column (d) line 1 for additional details regarding the system software included in Intangible Plant. Note that software is typically amortized over a 5 year period unless another life is deemed more appropriate.

The amortization charges shown in Column (d), Line 7 and Line 8 represent the amortization of costs for three Transmission Right-of Way Easements and two Distribution Right-of Way Easement, respectively, based on the periods covered by the Easements.

The amortization charges shown in Column (d), Line 10 - General Plant represent the amortization of three leasehold improvements over the lives of the respective leases.

(b) Concept: DepreciationAndAmortization


The amount of depreciation expense associated with Account 397 (Communication Equipment) for the year 2024 is $60,626,215 - 30.18% of such amount is directly assignable to the Transmission function and 69.82% of such amount is directly assignable to the Distribution function.


This note pertains to all plant accounts on Page 337 in Column (a), excluding transportation. Depreciation is computed monthly by taking the monthly depreciation rate times the average depreciable plant-in-service balances at the beginning and end of each month. The amounts shown in Column (b) are the annual average depreciable plan-in-service balances computed by dividing the sum of the monthly average plant-in-service balances for the year by twelve.

(d) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges


General Notes for Page 337: Page 337, Section C excludes all amortized Limited Term Plant (software, leasehold improvements, right of ways, etc.) as referenced in the footnote for Page 336, Line No. 1, Column (d). The Company provides depreciation on a straight-line basis by amortizing the cost of depreciable electric plant-in-service over estimated service lives for each class of plant. The annual average depreciable plant base for [a] Transmission, [b] Distribution - excluding HVD, Line Transformers and Meters, [c] Distribution High Voltage is reduced by $6,822,126,063, $19,796,287,020 and $4,358,623,232, respectively, related to estimated unrecorded retirements of certain plant-in-service.

(e) Concept: UtilityPlantAppliedDepreciationRate


A composite rate is calculated for all depreciation groups; therefore, an individual mortality curve is not available.

(f) Concept: UtilityPlantAppliedDepreciationRate


A composite rate is calculated for all depreciation groups; therefore, an individual mortality curve is not available.

(g) Concept: UtilityPlantAppliedDepreciationRate


A composite rate is calculated for all depreciation groups; therefore, an individual mortality curve is not available.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

REGULATORY COMMISSION EXPENSES
Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous years, if being amortized) relating to format cases before a regulatory body, or cases in which such a body was a party. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization of amounts deferred in previous years. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization. List in columns (f), (g), and (h), expenses incurred during the year which were charged currently to income, plant, or other accounts. Minor items (less than $25,000) may be grouped.
						EXPENSES INCURRED DURING YEAR				AMORTIZED DURING YEAR
						CURRENTLY CHARGED TO
Line No.	RegulatoryCommissionDescription Description (Furnish name of regulatory commission or body the docket or case number and a description of the case) (a)	RegulatoryExpensesAssessedByRegulatoryCommission Assessed by Regulatory Commission (b)	RegulatoryExpensesOfUtility Expenses of Utility (c)	RegulatoryCommissionExpensesAmount Total Expenses for Current Year (b) + (c) (d)	OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 at Beginning of Year (e)	NameOfDepartmentRegulatoryCommissionExpensesCharged Department (f)	AccountNumberRegulatoryCommissionExpensesCharged Account No. (g)	RegulatoryComissionExpensesIncurredAndCharged Amount (h)	RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets Deferred to Account 182.3 (i)	DeferredRegulatoryCommissionExpensesAmortizedInContraAccount Contra Account (j)	DeferredRegulatoryCommissionExpensesAmortized Amount (k)	OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 End of Year (l)
1	Illinois Commerce Commission
2	-------------------------------------
3	Docket Nos. -
4	20-0629, 22-0424, 22-0520, 22-0784, 23-0197, 23-0269,
5	23-0341, 23-0355, 23-0476, 23-0503, 23-0504, 23-0553,
6	23-0610, 23-0622, 23-0675, 23-0710, 23-0722, 23-0731,
7	23-0734, 23-0743, 23-0770, 23-0834, 24-0036, 24-0048,
8	24-0049, 24-0147, 24-0266, 24-0272, 24-0313, 24-0460,
9	24-0532, 24-0586, 24-0617, 24-0680, 24-0711, 24-0813,
10	24-0866, 24-0896, 24-0912, 24-0915, 24-0916,
11	Various complaint and petition matters		221,000	221,000			928	221,000
12	Docket No. 22-0067 Performance Metrics		124,777	124,777			928	124,777
13	Docket No. 22-0653 Part 280		27,635	27,635			928	27,635
14	Docket No. 24-0163 Low Income Rate Study		317,090	317,090			928	317,090
15	Docket No. docket anticipated Value of DER		681,129	681,129			928	681,129
16	Docket No. 24-0304 Annual Formula rate update and revenue reconciliation		84,922	84,922			928	84,922
17	Docket No. 24-0181 Refiled Grid Plan		77,022	77,022			928	77,022
18	Docket No. 23-0773 Rider IMUD		53,840	53,840			928	53,840
19	Docket No. 23-0055 Verified Petition for Approval of a Multi-Year Rate Plan - amortized over 4 years (2024-2027)		1,404,854	1,404,854	5,221,171		928	5,197,182	6,796,828		3,004,500	9,013,499
20	Annual Ethics & Compliance Fees		627,371	627,371			928	627,371
21	Various ICC dockets		42,410	42,410			928	42,410
22	Federal Energy Regulatory Commission
23	Deferred Tax Recovery		1,400	1,400			928	1,400
24	Docket No. FA21-5-000 - FERC Audit		223,168	223,168			928	223,168
25	Various FERC dockets		84,239	84,239			928	84,239
46	TOTAL		3,970,857	3,970,857	5,221,171			7,763,185	6,796,828		3,004,500	9,013,499

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D and D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(Identify recipient regardless of affiliation.) For any R, D and D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts). Indicate in column (a) the applicable classification, as shown below: Classifications: Electric R, D and D Performed Internally: Generation hydroelectric Recreation fish and wildlife Other hydroelectric Fossil-fuel steam Internal combustion or gas turbine Nuclear Unconventional generation Siting and heat rejection Transmission Overhead Underground Distribution Regional Transmission and Market Operation Environment (other than equipment) Other (Classify and include items in excess of $50,000.) Total Cost Incurred Electric, R, D and D Performed Externally: Research Support to the electrical Research Council or the Electric Power Research Institute Research Support to Edison Electric Institute Research Support to Nuclear Power Groups Research Support to Others (Classify) Total Cost Incurred Include in column (c) all R, D and D items performed internally and in column (d) those items performed outside the company costing $50,000 or more, briefly describing the specific area of R, D and D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D and D activity. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year, listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e). Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, Development, and Demonstration Expenditures, Outstanding at the end of the year. If costs have not been segregated for R, D and D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by ""Est."" Report separately research and related testing facilities operated by the respondent.
					AMOUNTS CHARGED IN CURRENT YEAR
Line No.	ResearchDevelopmentAndDemonstrationClassification Classification (a)	ResearchDevelopmentAndDemonstrationDescription Description (b)	ResearchDevelopmentAndDemonstrationCostsIncurredInternally Costs Incurred Internally Current Year (c)	ResearchDevelopmentAndDemonstrationCostsIncurredExternally Costs Incurred Externally Current Year (d)	AccountNumberForResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Account (e)	ResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Amount (f)	ResearchDevelopmentAndDemonstrationExpenditures Unamortized Accumulation (g)
1	B-1	EPRI Selected Programs		397,746	566	397,746
2	B-1	EPRI Selected Programs		738,672	588	738,672
3	B-2	CEA Technologies Inc. Program		88,126	566	88,126
4	B-2	CEA Technologies Inc. Program		30,963	588	30,963
5	B-2	Georgia Tech Research Corp. - NEETRAC		25,525	566	25,525
6	B-2	Georgia Tech Research Corp. - NEETRAC		26,567	588	26,567
7	B-2	Watson & Renner		17,014	566	17,014
8	B-2	Watson & Renner		17,014	588	17,014
9	Total			1,341,627		1,341,627

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

DISTRIBUTION OF SALARIES AND WAGES
Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used.
Line No.	Classification (a)	Direct Payroll Distribution (b)	Allocation of Payroll Charged for Clearing Accounts (c)	Total (d)
1	SalariesAndWagesElectricAbstract Electric
2	SalariesAndWagesElectricOperationAbstract Operation
3	SalariesAndWagesElectricOperationProduction Production	1,131,060
4	SalariesAndWagesElectricOperationTransmission Transmission	28,305,834
5	SalariesAndWagesElectricOperationRegionalMarket Regional Market
6	SalariesAndWagesElectricOperationDistribution Distribution	66,531,271
7	SalariesAndWagesElectricOperationCustomerAccounts Customer Accounts	108,004,844
8	SalariesAndWagesElectricOperationCustomerServiceAndInformational Customer Service and Informational	6,850,875
9	SalariesAndWagesElectricOperationSales Sales
10	SalariesAndWagesElectricOperationAdministrativeAndGeneral Administrative and General	62,149,600
11	SalariesAndWagesElectricOperation TOTAL Operation (Enter Total of lines 3 thru 10)	272,973,484
12	SalariesAndWagesElectricMaintenanceAbstract Maintenance
13	SalariesAndWagesElectricMaintenanceProduction Production
14	SalariesAndWagesElectricMaintenanceTransmission Transmission	19,091,636
15	SalariesAndWagesElectricMaintenanceRegionalMarket Regional Market
16	SalariesAndWagesElectricMaintenanceDistribution Distribution	95,369,791
17	SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral Administrative and General	3,855,915
18	SalariesAndWagesElectricMaintenance TOTAL Maintenance (Total of lines 13 thru 17)	118,317,342
19	SalariesAndWagesElectricOperationAndMaintenanceAbstract Total Operation and Maintenance
20	SalariesAndWagesElectricProduction Production (Enter Total of lines 3 and 13)	1,131,060
21	SalariesAndWagesElectricTransmission Transmission (Enter Total of lines 4 and 14)	47,397,470
22	SalariesAndWagesElectricRegionalMarket Regional Market (Enter Total of Lines 5 and 15)
23	SalariesAndWagesElectricDistribution Distribution (Enter Total of lines 6 and 16)	161,901,062
24	SalariesAndWagesElectricCustomerAccounts Customer Accounts (Transcribe from line 7)	108,004,844
25	SalariesAndWagesElectricCustomerServiceAndInformational Customer Service and Informational (Transcribe from line 8)	6,850,875
26	SalariesAndWagesElectricSales Sales (Transcribe from line 9)
27	SalariesAndWagesElectricAdministrativeAndGeneral Administrative and General (Enter Total of lines 10 and 17)	66,005,515
28	SalariesAndWagesElectricOperationAndMaintenance TOTAL Oper. and Maint. (Total of lines 20 thru 27)	391,290,826	109,137,339	500,428,165
29	SalariesAndWagesGasAbstract Gas
30	SalariesAndWagesGasOperationAbstract Operation
31	SalariesAndWagesGasOperationProductionManufacturedGas Production - Manufactured Gas
32	SalariesAndWagesGasOperationProductionNaturalGas Production-Nat. Gas (Including Expl. And Dev.)
33	SalariesAndWagesGasOperationOtherGasSupply Other Gas Supply
34	SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing Storage, LNG Terminaling and Processing
35	SalariesAndWagesGasOperationTransmission Transmission
36	SalariesAndWagesGasOperationDistribution Distribution
37	SalariesAndWagesGasCustomerAccounts Customer Accounts
38	SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational
39	SalariesAndWagesGasSales Sales
40	SalariesAndWagesGasOperationAdministrativeAndGeneral Administrative and General
41	SalariesAndWagesGasOperation TOTAL Operation (Enter Total of lines 31 thru 40)
42	SalariesAndWagesGasMaintenanceAbstract Maintenance
43	SalariesAndWagesGasMaintenanceProductionManufacturedGas Production - Manufactured Gas
44	SalariesAndWagesGasMaintenanceProductionNaturalGas Production-Natural Gas (Including Exploration and Development)
45	SalariesAndWagesGasMaintenanceOtherGasSupply Other Gas Supply
46	SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing
47	SalariesAndWagesGasMaintenanceTransmission Transmission
48	SalariesAndWagesGasMaintenanceDistribution Distribution
49	SalariesAndWagesGasMaintenanceAdministrativeAndGeneral Administrative and General
50	SalariesAndWagesGasMaintenance TOTAL Maint. (Enter Total of lines 43 thru 49)
51	SalariesAndWagesGasOperationAndMaintenanceAbstract Total Operation and Maintenance
52	SalariesAndWagesGasProductionManufacturedGas Production-Manufactured Gas (Enter Total of lines 31 and 43)
53	SalariesAndWagesGasProductionNaturalGas Production-Natural Gas (Including Expl. and Dev.) (Total lines 32,
54	SalariesAndWagesGasOtherGasSupply Other Gas Supply (Enter Total of lines 33 and 45)
55	SalariesAndWagesGasStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing (Total of lines 31 thru
56	SalariesAndWagesGasTransmission Transmission (Lines 35 and 47)
57	SalariesAndWagesGasDistribution Distribution (Lines 36 and 48)
58	SalariesAndWagesGasCustomerAccounts Customer Accounts (Line 37)
59	SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational (Line 38)
60	SalariesAndWagesGasSales Sales (Line 39)
61	SalariesAndWagesGasAdministrativeAndGeneral Administrative and General (Lines 40 and 49)
62	SalariesAndWagesGasOperationAndMaintenance TOTAL Operation and Maint. (Total of lines 52 thru 61)
63	SalariesAndWagesOtherUtilityDepartmentsAbstract Other Utility Departments
64	SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance Operation and Maintenance
65	SalariesAndWagesOperationsAndMaintenance TOTAL All Utility Dept. (Total of lines 28, 62, and 64)	391,290,826	109,137,339	500,428,165
66	SalariesAndWagesUtilityPlantAbstract Utility Plant
67	SalariesAndWagesUtilityPlantConstructionAbstract Construction (By Utility Departments)
68	SalariesAndWagesUtilityPlantConstructionElectricPlant Electric Plant	416,663,068	151,175,878	567,838,946
69	SalariesAndWagesUtilityPlantConstructionGasPlant Gas Plant
70	SalariesAndWagesUtilityPlantConstructionOther Other (provide details in footnote):
71	SalariesAndWagesUtilityPlantConstruction TOTAL Construction (Total of lines 68 thru 70)	416,663,068	151,175,878	567,838,946
72	SalariesAndWagesPlantRemovalAbstract Plant Removal (By Utility Departments)
73	SalariesAndWagesPlantRemovalElectricPlant Electric Plant	44,787,083	12,014,965	56,802,048
74	SalariesAndWagesPlantRemovalGasPlant Gas Plant
75	SalariesAndWagesPlantRemovalOther Other (provide details in footnote):
76	SalariesAndWagesPlantRemoval TOTAL Plant Removal (Total of lines 73 thru 75)	44,787,083	12,014,965	56,802,048
77	SalariesAndWagesOtherAccountsAbstract Other Accounts (Specify, provide details in footnote):
78	SalariesAndWagesOtherAccountsDescription Other Accounts (Specify, provide details in footnote):
79	SalariesAndWagesOtherAccountsDescription Stores Expense Undistributed	20,613,226	20,613,226
80	SalariesAndWagesOtherAccountsDescription Clearing Accounts	74,447,034	74,447,034
81	SalariesAndWagesOtherAccountsDescription Miscellaneous	(a) 37,464,376		37,464,376
82	SalariesAndWagesOtherAccountsDescription
83	SalariesAndWagesOtherAccountsDescription
84	SalariesAndWagesOtherAccountsDescription
85	SalariesAndWagesOtherAccountsDescription
86	SalariesAndWagesOtherAccountsDescription
87	SalariesAndWagesOtherAccountsDescription
88	SalariesAndWagesOtherAccountsDescription
89	SalariesAndWagesOtherAccountsDescription
90	SalariesAndWagesOtherAccountsDescription
91	SalariesAndWagesOtherAccountsDescription
92	SalariesAndWagesOtherAccountsDescription
93	SalariesAndWagesOtherAccountsDescription
94	SalariesAndWagesOtherAccountsDescription
95	SalariesAndWagesOtherAccounts TOTAL Other Accounts	132,524,636	95,060,260	37,464,376
96	SalariesAndWagesGeneralExpense TOTAL SALARIES AND WAGES	985,265,613	177,267,922	1,162,533,535

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: SalariesAndWagesOtherAccounts


Includes direct labor charges related to non-utility operations.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

COMMON UTILITY PLANT AND EXPENSES
Describe the property carried in the utility's accounts as common utility plant and show the book cost of such plant at end of year classified by accounts as provided by Electric Plant Instruction 13, Common Utility Plant, of the Uniform System of Accounts. Also show the allocation of such plant costs to the respective departments using the common utility plant and explain the basis of allocation used, giving the allocation factors. Furnish the accumulated provisions for depreciation and amortization at end of year, showing the amounts and classifications of such accumulated provisions, and amounts allocated to utility departments using the common utility plant to which such accumulated provisions relate, including explanation of basis of allocation and factors used. Give for the year the expenses of operation, maintenance, rents, depreciation, and amortization for common utility plant classified by accounts as provided by the Uniform System of Accounts. Show the allocation of such expenses to the departments using the common utility plant to which such expenses are related. Explain the basis of allocation used and give the factors of allocation. Give date of approval by the Commission for use of the common utility plant classification and reference to the order of the Commission or other authorization.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No.	Description of Item(s) (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1	Energy
2	Net Purchases (Account 555)	178,225,908	347,282,581	601,426,073	(a) 751,593,712
2.1	Net Purchases (Account 555.1)
3	Net Sales (Account 447)	3,748,882	8,576,542	16,437,338	20,927,736
4	Transmission Rights
5	Ancillary Services	10,510,664	22,777,922	33,804,810	(b) 44,595,812
6	Other Items (list separately)
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46	TOTAL	192,485,454	378,637,045	651,668,221	817,117,260

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: IsoOrRtoSettlementsEnergyNetPurchasesPurchasedPower


Amounts reported in Line Nos. 2, 3 & 5 reflect the year-to-date activities through the end of the applicable quarter.

(b) Concept: IsoOrRtoSettlementsAncillaryServices


Purchases and sales of ancillary services were recorded in the following accounts:

Purchases
Account 555	$	43,037,882
Account 561.4	14,870,870
Account 561.8	756,023
Account 575.7	8,464,510
Sales
Account 456.1	(22,533,473)
Total	$	44,595,812

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

PURCHASES AND SALES OF ANCILLARY SERVICES
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff. In columns for usage, report usage-related billing determinant and the unit of measure. On Line 1 columns (b), (c), (d), and (e) report the amount of ancillary services purchased and sold during the year. On Line 2 columns (b), (c), (d), and (e) report the amount of reactive supply and voltage control services purchased and sold during the year. On Line 3 columns (b), (c), (d), and (e) report the amount of regulation and frequency response services purchased and sold during the year. On Line 4 columns (b), (c), (d), and (e) report the amount of energy imbalance services purchased and sold during the year. On Lines 5 and 6, columns (b), (c), (d), and (e) report the amount of operating reserve spinning and supplement services purchased and sold during the period. On Line 7 columns (b), (c), (d), and (e) report the total amount of all other types ancillary services purchased or sold during the year. Include in a footnote and specify the amount for each type of other ancillary service provided.
		Amount Purchased for the Year			Amount Sold for the Year
		Usage - Related Billing Determinant			Usage - Related Billing Determinant
Line No.	Type of Ancillary Service (a)	Number of Units (b)	Unit of Measure (c)	Dollar (d)	Number of Units (e)	Unit of Measure (f)	Dollars (g)
1	Scheduling, System Control and Dispatch	32,119,127	MWH	22,369,917	93,285,395	MWH	(a) 22,533,473
2	Reactive Supply and Voltage			(b) 21,854,247
3	Regulation and Frequency Response			(c) 7,242,818
4	Energy Imbalance
5	Operating Reserve - Spinning			(d) 3,436,049
6	Operating Reserve - Supplement			(e) 6,628,616
7	Other			(f) 5,597,638
8	Total (Lines 1 thru 7)	32,119,127		67,129,285	93,285,395		22,533,473

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: AncillaryServicesSoldAmount


Represents revenues allocated to the respondent from PJM Interconnection, LLC.

(b) Concept: AncillaryServicesPurchasedAmount


Represents the per load ratio share.


This footnote applies to the cells in lines 3, 5, and 6, column d. The number of units applicable to Line No. 3, Column (b) is 32,119,127.

(d) Concept: AncillaryServicesPurchasedAmount


This footnote applies to the cells in lines 3, 5, and 6, column d. The number of units applicable to Line No. 3, Column (b) is 32,119,127.

(e) Concept: AncillaryServicesPurchasedAmount


This footnote applies to the cells in lines 3, 5, and 6, column d. The number of units applicable to Line No. 3, Column (b) is 32,119,127.

(f) Concept: AncillaryServicesPurchasedAmount


The details of this "Other" amount are as follows:

Black Start service charge	$	3,889,994
Schedule 10 - NERC charges	696,008
Schedule 10 - RFC charges	1,005,279
Reconciliation of Schedule 10 charges	956
Consumer Advocates of PJM States, Inc. (CAPS)	19,244
Fuel Cost Policy Penalty	(13,843)
	$	5,597,638

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

MONTHLY TRANSMISSION SYSTEM PEAK LOAD
Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No.	Month (a)	Monthly Peak MW - Total (b)	Day of Monthly Peak (c)	Hour of Monthly Peak (d)	Firm Network Service for Self (e)	Firm Network Service for Others (f)	Long-Term Firm Point-to-point Reservations (g)	Other Long-Term Firm Service (h)	Short-Term Firm Point-to-point Reservation (i)	Other Service (j)
	NAME OF SYSTEM: 0
1	January	15,077	16	(a) 17	6,029	9,048
2	February	11,845	16	18	4,243	7,602
3	March	11,534	19	7	3,674	7,860
4	Total for Quarter 1				13,946	24,510	0	0	0	0
5	April	11,472	3	9	3,625	7,847
6	May	16,015	21	17	6,567	9,448
7	June	19,874	17	17	9,161	10,713
8	Total for Quarter 2				19,353	28,008	0	0	0	0
9	July	19,220	15	17	8,716	10,504
10	August	21,560	27	16	9,821	11,739
11	September	16,871	20	16	7,110	9,761
12	Total for Quarter 3				25,647	32,004	0	0	0	0
13	October	11,806	30	15	3,616	8,190
14	November	12,040	21	17	4,311	7,729
15	December	14,063	12	17	5,447	8,616
16	Total for Quarter 4				13,374	24,535	0	0	0	0
17	Total				72,320	109,057	0	0	0	0

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: HourOfMonthlyPeakExcludingIsoAndRto

All hours reported in Column (d) are presented in Central Standard Time (CST) since ComEd Operations are in that time zone.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

Monthly ISO/RTO Transmission System Peak Load
Report the monthly peak load on the respondent's transmission system. If the Respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Column (c) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (i) by month the system’s transmission usage by classification. Amounts reported as Through and Out Service in Column (g) are to be excluded from those amounts reported in Columns (e) and (f). Amounts reported in Column (j) for Total Usage is the sum of Columns (h) and (i).
Line No.	Month (a)	Monthly Peak MW - Total (b)	Day of Monthly Peak (c)	Hour of Monthly Peak (d)	Import into ISO/RTO (e)	Exports from ISO/RTO (f)	Through and Out Service (g)	Network Service Usage (h)	Point-to-Point Service Usage (i)	Total Usage (j)
	NAME OF SYSTEM: 0
1	January
2	February
3	March
4	Total for Quarter 1				0	0	0	0	0	0
5	April
6	May
7	June
8	Total for Quarter 2				0	0	0	0	0	0
9	July
10	August
11	September
12	Total for Quarter 3				0	0	0	0	0	0
13	October
14	November
15	December
16	Total for Quarter 4				0	0	0	0	0	0
17	Total Year to Date/Year				0	0	0	0	0	0

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2024-12-31

Year/Period of Report

End of:

2024

ELECTRIC ENERGY ACCOUNT
Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year.
Line No.	Item (a)	MegaWatt Hours (b)	Line No.	Item (a)	MegaWatt Hours (b)
1	SOURCES OF ENERGY		21	DISPOSITION OF ENERGY
2	Generation (Excluding Station Use):		22	Sales to Ultimate Consumers (Including Interdepartmental Sales)	(a)(b) 84,331,195
3	Steam		23	Requirements Sales for Resale (See instruction 4, page 311.)
4	Nuclear		24	Non-Requirements Sales for Resale (See instruction 4, page 311.)	791,465
5	Hydro-Conventional		25	Energy Furnished Without Charge	394,273
6	Hydro-Pumped Storage		26	Energy Used by the Company (Electric Dept Only, Excluding Station Use)
7	Other		27	Total Energy Losses	5,897,079
8	Less Energy for Pumping		27.1	Total Energy Stored
9	Net Generation (Enter Total of lines 3 through 8)	0	28	TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES	91,414,012
10	Purchases (other than for Energy Storage)	(c) 32,670,709
10.1	Purchases for Energy Storage	0
11	Power Exchanges:
12	Received	0
13	Delivered	0
14	Net Exchanges (Line 12 minus line 13)	0
15	Transmission For Other (Wheeling)
16	Received	58,743,303
17	Delivered
18	Net Transmission for Other (Line 16 minus line 17)	58,743,303
19	Transmission By Others Losses
20	TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19)	91,414,012

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2024-12-31

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: MegawattHoursSoldSalesToUltimateConsumers


	MWh's for the Years Ended December 31,
	2024		2023
Retail deliveries for Full Service	$	30,116,920	$	29,964,172
Retail deliveries for Delivery Only	54,214,275		52,326,049
Total retail deliveries	$	84,331,195	$	82,290,221

General Notes:
Full Service reflects deliveries to customers taking electric service under tariff rates. Delivery Only service reflects customers electing to receive electricity from Alternative Retail Electric Suppliers.

(b) Concept: MegawattHoursSoldSalesToUltimateConsumers


Retail deliveries for Full Service	$	30,116,920
Retail deliveries for Delivery Only	54,214,275
Total Sales to Ultimate Customers	$	84,331,195

Refer to the footnote on Page 300, line No. 10, Column (d) for additional details.


Reflects utility zone load, which includes the following amounts purchased by ComEd to serve its Full Service customers.

	1Q 2024 Month	MWhs
	January	3,003,195
	February	2,483,577
	March	2,346,099
	Quarter Total	7,832,871

	2Q 2024 Month	MWhs
	April	1,965,250
	May	2,281,136
	June	3,353,019
	Quarter Total	7,599,405

	3Q 2024 Month	MWhs
	July	3,436,174
	August	3,380,589
	September	2,969,571
	Quarter Total	9,786,334

	4Q 2024 Month	MWhs
	October	2,346,387
	November	2,291,127
	December	2,814,585
	Quarter Total	7,452,099

	YTD Total	32,670,709

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

MONTHLY PEAKS AND OUTPUT
Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system. Report in column (b) by month the system’s output in Megawatt hours for each month. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).
Line No.	MonthAxis Month (a)	EnergyActivity Total Monthly Energy (b)	NonRequiredSalesForResaleEnergy Monthly Non-Requirement Sales for Resale & Associated Losses (c)	MonthlyPeakLoad Monthly Peak - Megawatts (d)	DayOfMonthlyPeak Monthly Peak - Day of Month (e)	HourOfMonthlyPeak Monthly Peak - Hour (f)
	NAME OF SYSTEM: 0
29	January	8,176,148	31,562	15,077	16	(a) 17
30	February	6,851,534	77,657	11,845	16	18
31	March	6,942,682	48,189	11,534	19	7
32	April	6,506,082	38,372	11,472	3	9
33	May	7,038,256	42,880	16,015	21	17
34	June	8,578,764	99,261	19,874	17	17
35	July	9,019,264	129,310	19,220	15	17
36	August	9,084,276	60,962	21,560	27	16
37	September	7,680,383	70,885	16,871	20	16
38	October	6,852,062	78,261	11,806	30	15
39	November	6,806,358	62,126	12,040	21	17
40	December	7,878,203	52,000	14,063	12	17
41	Total	91,414,012	791,465

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: HourOfMonthlyPeak


Hours reported in Column (f) are presented in the Central Standard Time (CST) since ComEd operations are in that time zone.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

Steam Electric Generating Plant Statistics

1. Report data for plant in Service only.
2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants.
3. Indicate by a footnote any plant leased or operated as a joint facility.
4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.
5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.
6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mcf.
7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20.
8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned.
9. Items under Cost of Plant are based on USofA accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.
10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.
11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.
12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant.

Line No.	Item (a)	Plant Name: 0
1	PlantKind Kind of Plant (Internal Comb, Gas Turb, Nuclear)
2	PlantConstructionType Type of Constr (Conventional, Outdoor, Boiler, etc)
3	YearPlantOriginallyConstructed Year Originally Constructed
4	YearLastUnitOfPlantInstalled Year Last Unit was Installed
5	InstalledCapacityOfPlant Total Installed Cap (Max Gen Name Plate Ratings-MW)
6	NetPeakDemandOnPlant Net Peak Demand on Plant - MW (60 minutes)
7	PlantHoursConnectedToLoad Plant Hours Connected to Load
8	NetContinuousPlantCapability Net Continuous Plant Capability (Megawatts)
9	NetContinuousPlantCapabilityNotLimitedByCondenserWater When Not Limited by Condenser Water
10	NetContinuousPlantCapabilityLimitedByCondenserWater When Limited by Condenser Water
11	PlantAverageNumberOfEmployees Average Number of Employees
12	NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh
13	CostOfLandAndLandRightsSteamProduction Cost of Plant: Land and Land Rights
14	CostOfStructuresAndImprovementsSteamProduction Structures and Improvements
15	CostOfEquipmentSteamProduction Equipment Costs
16	AssetRetirementCostsSteamProduction Asset Retirement Costs
17	CostOfPlant Total cost (total 13 thru 20)
18	CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 17/5) Including
19	OperationSupervisionAndEngineeringExpense Production Expenses: Oper, Supv, & Engr
20	FuelSteamPowerGeneration Fuel
21	CoolantsAndWater Coolants and Water (Nuclear Plants Only)
22	SteamExpensesSteamPowerGeneration Steam Expenses
23	SteamFromOtherSources Steam From Other Sources
24	SteamTransferredCredit Steam Transferred (Cr)
25	ElectricExpensesSteamPowerGeneration Electric Expenses
26	MiscellaneousSteamPowerExpenses Misc Steam (or Nuclear) Power Expenses
27	RentsSteamPowerGeneration Rents
28	Allowances Allowances
29	MaintenanceSupervisionAndEngineeringSteamPowerGeneration Maintenance Supervision and Engineering
30	MaintenanceOfStructuresSteamPowerGeneration Maintenance of Structures
31	MaintenanceOfBoilerPlantSteamPowerGeneration Maintenance of Boiler (or reactor) Plant
32	MaintenanceOfElectricPlantSteamPowerGeneration Maintenance of Electric Plant
33	MaintenanceOfMiscellaneousSteamPlant Maintenance of Misc Steam (or Nuclear) Plant
34	PowerProductionExpensesSteamPower Total Production Expenses	0
35	ExpensesPerNetKilowattHour Expenses per Net kWh

35	FuelKindAxis Plant Name
36	FuelKind Fuel Kind
37	FuelUnit Fuel Unit
38	QuantityOfFuelBurned Quantity (Units) of Fuel Burned
39	FuelBurnedAverageHeatContent Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)
40	AverageCostOfFuelPerUnitAsDelivered Avg Cost of Fuel/unit, as Delvd f.o.b. during year
41	AverageCostOfFuelPerUnitBurned Average Cost of Fuel per Unit Burned
42	AverageCostOfFuelBurnedPerMillionBritishThermalUnit Average Cost of Fuel Burned per Million BTU
43	AverageCostOfFuelBurnedPerKilowattHourNetGeneration Average Cost of Fuel Burned per kWh Net Gen
44	AverageBritishThermalUnitPerKilowattHourNetGeneration Average BTU per kWh Net Generation

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

Hydroelectric Generating Plant Statistics

Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings).
If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number.
If net peak demand for 60 minutes is not available, give that which is available specifying period.
If a group of employees attends more than one generating plant, report on line 11 the approximate average number of employees assignable to each plant.
The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
Report as a separate plant any plant equipped with combinations of steam, hydro, internal combustion engine, or gas turbine equipment.

Line No.	Item (a)	FERC Licensed Project No. 0 Plant Name: 0
1	PlantKind Kind of Plant (Run-of-River or Storage)
2	PlantConstructionType Plant Construction type (Conventional or Outdoor)
3	YearPlantOriginallyConstructed Year Originally Constructed
4	YearLastUnitOfPlantInstalled Year Last Unit was Installed
5	InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW)
6	NetPeakDemandOnPlant Net Peak Demand on Plant-Megawatts (60 minutes)
7	PlantHoursConnectedToLoad Plant Hours Connect to Load
8	NetPlantCapabilityAbstract Net Plant Capability (in megawatts)
9	NetPlantCapabilityUnderMostFavorableOperatingConditions (a) Under Most Favorable Oper Conditions
10	NetPlantCapabilityUnderMostAdverseOperatingConditions (b) Under the Most Adverse Oper Conditions
11	PlantAverageNumberOfEmployees Average Number of Employees
12	NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh
13	CostOfPlantAbstract Cost of Plant
14	CostOfLandAndLandRightsHydroelectricProduction Land and Land Rights
15	CostOfStructuresAndImprovementsHydroelectricProduction Structures and Improvements
16	CostOfReservoirsDamsAndWaterwaysHydroelectricProduction Reservoirs, Dams, and Waterways
17	EquipmentCostsHydroelectricProduction Equipment Costs
18	CostOfRoadsRailroadsAndBridgesHydroelectricProduction Roads, Railroads, and Bridges
19	AssetRetirementCostsHydroelectricProduction Asset Retirement Costs
20	CostOfPlant Total cost (total 13 thru 20)
21	CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 20 / 5)
22	ProductionExpensesAbstract Production Expenses
23	OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering
24	WaterForPower Water for Power
25	HydraulicExpenses Hydraulic Expenses
26	ElectricExpensesHydraulicPowerGeneration Electric Expenses
27	MiscellaneousHydraulicPowerGenerationExpenses Misc Hydraulic Power Generation Expenses
28	RentsHydraulicPowerGeneration Rents
29	MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration Maintenance Supervision and Engineering
30	MaintenanceOfStructuresHydraulicPowerGeneration Maintenance of Structures
31	MaintenanceOfReservoirsDamsAndWaterways Maintenance of Reservoirs, Dams, and Waterways
32	MaintenanceOfElectricPlantHydraulicPowerGeneration Maintenance of Electric Plant
33	MaintenanceOfMiscellaneousHydraulicPlant Maintenance of Misc Hydraulic Plant
34	PowerProductionExpensesHydraulicPower Total Production Expenses (total 23 thru 33)
35	ExpensesPerNetKilowattHour Expenses per net kWh

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

Pumped Storage Generating Plant Statistics
Large plants and pumped storage plants of 10,000 Kw or more of installed capacity (name plate ratings). If any plant is leased, operating under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. Give project number. If net peak demand for 60 minutes is not available, give that which is available, specifying period. If a group of employees attends more than one generating plant, report on Line 8 the approximate average number of employees assignable to each plant. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power System Control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses." Pumping energy (Line 10) is that energy measured as input to the plant for pumping purposes. Include on Line 36 the cost of energy used in pumping into the storage reservoir. When this item cannot be accurately computed leave Lines 36, 37 and 38 blank and describe at the bottom of the schedule the company's principal sources of pumping power, the estimated amounts of energy from each station or other source that individually provides more than 10 percent of the total energy used for pumping, and production expenses per net MWH as reported herein for each source described. Group together stations and other resources which individually provide less than 10 percent of total pumping energy. If contracts are made with others to purchase power for pumping, give the supplier contract number, and date of contract.
Line No.	Item (a)	FERC Licensed Project No. 0 Plant Name: 0
1	PlantConstructionType Type of Plant Construction (Conventional or Outdoor)
2	YearPlantOriginallyConstructed Year Originally Constructed
3	YearLastUnitOfPlantInstalled Year Last Unit was Installed
4	InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW)
5	NetPeakDemandOnPlant Net Peak Demaind on Plant-Megawatts (60 minutes)	0
6	PlantHoursConnectedToLoad Plant Hours Connect to Load While Generating	0
7	NetContinuousPlantCapability Net Plant Capability (in megawatts)	0
8	PlantAverageNumberOfEmployees Average Number of Employees
9	NetGenerationExcludingPlantUse Generation, Exclusive of Plant Use - kWh	0
10	EnergyUsedForPumping Energy Used for Pumping
11	NetOutputForLoad Net Output for Load (line 9 - line 10) - Kwh	0
12	CostOfPlantAbstract Cost of Plant
13	CostOfLandAndLandRightsPumpedStoragePlant Land and Land Rights
14	CostOfStructuresAndImprovementsPumpedStoragePlant Structures and Improvements	0
15	CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant Reservoirs, Dams, and Waterways	0
16	CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant Water Wheels, Turbines, and Generators	0
17	CostOfAccessoryElectricEquipmentPumpedStoragePlant Accessory Electric Equipment	0
18	CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant Miscellaneous Powerplant Equipment	0
19	CostOfRoadsRailroadsAndBridgesPumpedStoragePlant Roads, Railroads, and Bridges	0
20	AssetRetirementCostsPumpedStoragePlant Asset Retirement Costs	0
21	CostOfPlant Total cost (total 13 thru 20)
22	CostPerKilowattOfInstalledCapacity Cost per KW of installed cap (line 21 / 4)
23	ProductionExpensesAbstract Production Expenses
24	OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering	0
25	WaterForPower Water for Power	0
26	PumpedStorageExpenses Pumped Storage Expenses	0
27	ElectricExpensesPumpedStoragePlant Electric Expenses	0
28	MiscellaneousPumpedStoragePowerGenerationExpenses Misc Pumped Storage Power generation Expenses	0
29	RentsPumpedStoragePlant Rents	0
30	MaintenanceSupervisionAndEngineeringPumpedStoragePlant Maintenance Supervision and Engineering	0
31	MaintenanceOfStructuresPumpedStoragePlant Maintenance of Structures	0
32	MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant Maintenance of Reservoirs, Dams, and Waterways	0
33	MaintenanceOfElectricPlantPumpedStoragePlant Maintenance of Electric Plant	0
34	MaintenanceOfMiscellaneousPumpedStoragePlant Maintenance of Misc Pumped Storage Plant	0
35	PowerProductionExpenseBeforePumpingExpenses Production Exp Before Pumping Exp (24 thru 34)
36	PumpingExpenses Pumping Expenses
37	PowerProductionExpensesPumpedStoragePlant Total Production Exp (total 35 and 36)
38	ExpensesPerNetKilowattHour Expenses per kWh (line 37 / 9)
39	ExpensesPerNetKilowattHourGenerationAndPumping Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10))	0

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

GENERATING PLANT STATISTICS (Small Plants)
Small generating plants are steam plants of, less than 25,000 Kw; internal combustion and gas turbine-plants, conventional hydro plants and pumped storage plants of less than 10,000 Kw installed capacity (name plate rating). Designate any plant leased from others, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, and give a concise statement of the facts in a footnote. If licensed project, give project number in footnote. List plants appropriately under subheadings for steam, hydro, nuclear, internal combustion and gas turbine plants. For nuclear, see instruction 11, Page 402. If net peak demand for 60 minutes is not available, give the which is available, specifying period. If any plant is equipped with combinations of steam, hydro internal combustion or gas turbine equipment, report each as a separate plant. However, if the exhaust heat from the gas turbine is utilized in a steam turbine regenerative feed water cycle, or for preheated combustion air in a boiler, report as one plant.
									Production Expenses
Line No.	PlantName Name of Plant (a)	YearPlantOriginallyConstructed Year Orig. Const. (b)	InstalledCapacityOfPlant Installed Capacity Name Plate Rating (MW) (c)	NetPeakDemandOnPlant Net Peak Demand MW (60 min) (d)	NetGenerationExcludingPlantUse Net Generation Excluding Plant Use (e)	CostOfPlant Cost of Plant (f)	PlantCostPerMw Plant Cost (Incl Asset Retire. Costs) Per MW (g)	OperatingExpensesExcludingFuel Operation Exc'l. Fuel (h)	FuelProductionExpenses Fuel Production Expenses (i)	MaintenanceProductionExpenses Maintenance Production Expenses (j)	FuelKind Kind of Fuel (k)	FuelCostPerMmbtus Fuel Costs (in cents (per Million Btu) (l)	GenerationType Generation Type (m)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

ENERGY STORAGE OPERATIONS (Large Plants)
Large Plants are plants of 10,000 Kw or more. In columns (a) (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location. In column (d), report Megawatt hours (MWH) purchased, generated, or received in exchange transactions for storage. In columns (e), (f) and (g) report MWHs delivered to the grid to support production, transmission and distribution. The amount reported in column (d) should include MWHs delivered/provided to a generator’s own load requirements or used for the provision of ancillary services. In columns (h), (i), and (j) report MWHs lost during conversion, storage and discharge of energy. In column (k) report the MWHs sold. In column (l), report revenues from energy storage operations. In a footnote, disclose the revenue accounts and revenue amounts related to the income generating activity. In column (m), report the cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. In columns (n) and (o), report fuel costs for storage operations associated with self-generated power included in Account 501 and other costs associated with self-generated power. In columns (q), (r) and (s) report the total project plant costs including but not exclusive of land and land rights, structures and improvements, energy storage equipment, turbines, compressors, generators, switching and conversion equipment, lines and equipment whose primary purpose is to integrate or tie energy storage assets into the power grid, and any other costs associated with the energy storage project included in the property accounts listed.
Line No.	Name of the Energy Storage Project (a)	Functional Classification (b)	Location of the Project (c)	MWHs (d)	MWHs delivered to the grid to support Production (e)	MWHs delivered to the grid to support Transmission (f)	MWHs delivered to the grid to support Distribution (g)	MWHs Lost During Conversion, Storage and Discharge of Energy Production (h)	MWHs Lost During Conversion, Storage and Discharge of Energy Transmission (i)	MWHs Lost During Conversion, Storage and Discharge of Energy Distribution (j)	MWHs Sold (k)	Revenues from Energy Storage Operations (l)	Power Purchased for Storage Operations (555.1) (Dollars) (m)	Fuel Costs from associated fuel accounts for Storage Operations Associated with Self- Generated Power (Dollars) (n)	Other Costs Associated with Self-Generated Power (Dollars) (o)	Account for Project Costs (p)	Production (Dollars) (q)	Transmission (Dollars) (r)	Distribution (Dollars) (s)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35	TOTAL			0	0	0	0	0	0	0	0	0	0	0	0		0	0	0

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

ENERGY STORAGE OPERATIONS (Small Plants)
Small Plants are plants less than 10,000 Kw. In columns (a), (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location. In column (d), report project plant cost including but not exclusive of land and land rights, structures and improvements, energy storage equipment and any other costs associated with the energy storage project. In column (e), report operation expenses excluding fuel, (f), maintenance expenses, (g) fuel costs for storage operations and (h) cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. If any other expenses, report in column (i) and footnote the nature of the item(s).
					BALANCE AT BEGINNING OF YEAR
Line No.	Name of the Energy Storage Project (a)	Functional Classification (b)	Location of the Project (c)	Project Cost (d)	Operations (Excluding Fuel used in Storage Operations) (e)	Maintenance (f)	Cost of fuel used in storage operations (g)	Account No. 555.1, Power Purchased for Storage Operations (h)	Other Expenses (i)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36	TOTAL			0	0	0	0	0	0

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

TRANSMISSION LINE STATISTICS
Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. If required by a State commission to report individual lines for all voltages, do so but do not group totals for each voltage under 132 kilovolts. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g). Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. Base the plant cost figures called for in columns (j) to (l) on the book cost at end of year.
	DESIGNATION		VOLTAGE (KV) - (Indicate where other than 60 cycle, 3 phase)			LENGTH (Pole miles) - (In the case of underground lines report circuit miles)				COST OF LINE (Include in column (j) Land, Land rights, and clearing right-of-way)			EXPENSES, EXCEPT DEPRECIATION AND TAXES
Line No.	TransmissionLineStartPoint From	TransmissionLineEndPoint To	OperatingVoltageOfTransmissionLine Operating	DesignedVoltageOfTransmissionLine Designated	SupportingStructureOfTransmissionLineType Type of Supporting Structure	LengthForStandAloneTransmissionLines On Structure of Line Designated	LengthForTransmissionLinesAggregatedWithOtherStructures On Structures of Another Line	NumberOfTransmissionCircuits Number of Circuits	SizeOfConductorAndMaterial Size of Conductor and Material	CostOfLandAndLandRightsTransmissionLines Land	ConstructionAndOtherCostsTransmissionLines Construction Costs	OverallCostOfTransmissionLine Total Costs	OperatingExpensesOfTransmissionLine Operation Expenses	MaintenanceExpensesOfTransmissionLine Maintenance Expenses	RentExpensesOfTransmissionLine Rents	OverallExpensesOfTransmissionLine Total Expenses
	(a)	(b)	(c)	(d)	(e)	(f)	(g)	(h)	(i)	(j)	(k)	(l)	(m)	(n)	(o)	(p)
1	(a) 138 KV Line									30,412,187	1,336,179,344	1,366,591,531
2	345 KV Line									91,507,142	1,427,246,217	1,518,753,359
3	765 KV Line									9,668,733	49,839,122	59,507,855
4	Overhead Line Expenses
5	Underground Line Expenses
6	765KV LINES OVERHEAD
7	2315 COLLINS	PLANO	765	765	ST	34.41		1	4-1585 AE ACAR
8	11215 WILTON CENTER	ILL-IND STATE LINE	765	765	ST	27.82		1	4-1277 ACAR
9	11216 WILTON CENTER - 1	COLLINS	765	765	ST	27.09		1	4-1585 AE ACAR
10	11216 WILTON CENTER - 2	COLLINS	765	765	SH	0.27			4-1585 AE ACAR
11	345KV LINES OVERHEAD								345kV LINES
12	0101 LASALLE - 1	PLANO	345	345	ST	28.64		1	2-1277 ACAR
13	0101 LASALLE - 2	PLANO	345	345	SP	12.32			2-1277 ACAR
14	0102 LASALLE - 1	PLANO	345	345	ST	0.47	28.14	1	2-1277 ACAR
15	0102 LASALLE - 2	PLANO	345	345	SP		12.32		2-1277 ACAR, 2-T2-1192 AAC
16	0103 LASALLE - 1	BRAIDWOOD	345	345	SP	24.86		1	2-1277 ACAR
17	0103 LASALLE - 2	BRAIDWOOD	345	345	ST	0.69			2-1277 ACAR
18	0104 LASALLE - 1	BRAIDWOOD	345	345	ST	0.58		1	2-1277 ACAR
19	0104 LASALLE - 2	BRAIDWOOD	345	345	SP		24.86		2-1277 ACAR
20	0301 POWERTON - 1	KATYDID	345	345	SP	1.89		1	2-1277 ACAR
21	0301 POWERTON - 2	KATYDID	345	345	ST	72.02			2-1277 ACAR
22	0302 POWERTON - 1	MOLE CREEK	345	345	SP	1.37		1	2-1277 ACAR
23	0302 POWERTON - 2	MOLE CREEK	345	345	ST	44.81			2-1277 ACAR
24	0303 POWERTON - 1	NEVADA	345	345	SP	1.11	0.20	1	2-1277 ACAR
25	0303 POWERTON - 2	NEVADA	345	345	ST	0.25	69.22		2-1277 ACAR
26	0304 POWERTON - 1	TAXEWELL (CILCO)	345	345	ST		8.79	1	2-1277 ACAR
27	0304 POWERTON - 2	TAXEWELL (CILCO)	345	345	ST	0.12			2-1277 ACAR
28	0403 QUAD CITIES - 1	CORDOVA	345	345	ST	1.96		1	2-1033.5 ACSS/TW
29	0403 QUAD CITIES - 2	CORDOVA	345	345	SP	0.17			2-1277 ACAR
30	0404 QUAD CITIES	N.W. STEEL & WIRE	345	345	ST	33.07		1	2-1277 ACAR
31	0621 BYRON - 1	CHERRY VALLEY	345	345	ST	0.27	13.17	1	2156 ACSR
32	0621 BYRON - 2	CHERRY VALLEY	345	345	SP	8.07			2156 ACSR
33	0622 BYRON - 1	CHERRY VALLEY	345	345	ST	21.51		1	2156 ACSR, 2338 A
34	0622 BYRON - 2	CHERRY VALLEY	345	345	SP	0.03			2156 ACSR
35	0624 BYRON - 1	WEMPLETOWN	345	345	ST	0.41		1	2156 ACSR
36	0624 BYRON - 2	WEMPLETOWN	345	345	SP	27.87			2156 ACSR, 2-2156
37	0626 BYRON	WAYNE	345	345	SP	59.44		1	2-1277 ACAR
38	0627 BYRON - 1	LEE COUNTY E.C.	345	345	ST	11.11		1	2-1277 ACAR
39	0627 BYRON - 2	LEE COUNTY E.C.	345	345	SP	0.07			2-1277 ACAR
40	0627 BYRON - 3	LEE COUNTY E.C.	345	345	ST	0.49			2156 ACSR
41	0627 BYRON - 4	LEE COUNTY E.C.	345	345	SP	7.80			2156 ACSR
42	0722 STATE LINE	BURNHAM	345	345	ST	3.83		1	2338 ACAR
43	1202 DRESDEN - 1	MULBERRY	345	345	SP	0.37		1	2156 ACSR
44	1202 DRESDEN - 2	MULBERRY	345	345	ST	1.12			2338 ACAR
45	1220 DRESDEN - 1	ELWOOD E.C.	345	345	ST		11.50	1	2338 ACAR
46	1220 DRESDEN - 2	ELWOOD E.C.	345	345	SP		0.40		T2-1113 ACSR
47	1220 DRESDEN - 3	ELWOOD E.C.	345	345	ST	0.53			2338 ACAR
48	1220 DRESDEN - 4	ELWOOD E.C.	345	345	SP	0.16			2156 ACSR
49	1221 DRESDEN - 1	WOLFS	345	345	ST	1.11		1	2338 ACAR
50	1221 DRESDEN - 2	WOLFS	345	345	ST	22.72			2156 ACSR
51	1221 DRESDEN - 3	WOLFS	345	345	SP	0.94			2156 ACSR
52	1222 DRESDEN - 1	ELWOOD E.C.	345	345	SP	0.54		1	T2-1113,2156 ACSR
53	1222 DRESDEN - 2	ELWOOD E.C.	345	345	ST	11.89			2338 ACAR
54	1223 DRESDEN - 1	ELECTRIC JUNCTION	345	345	ST	0.19	28.43	1	2156 ACSR
55	1223 DRESDEN - 2	ELECTRIC JUNCTION	345	345	ST	0.26	1.07		2338 ACAR
56	1223 DRESDEN - 3	ELECTRIC JUNCTION	345	345	SP	0.05	1.25		2156 ACSR
57	1227 DRESDEN - 1	MULBERRY	345	345	SP	0.56	0.18	1	2156 ACSR, 2-1033.5 ACSS/TW
58	1227 DRESDEN - 2	MULBERRY	345	345	ST	0.11	0.69		2156 ACSR
59	1309 CRAWFORD	FISK TERMINAL	345	345	SP	4.65		1	T2-1113 ACSR
60	1310 CRAWFORD	FISK	345	345	SP	0.18	4.39	1	T2-1113 ACSR
61	1311 CRAWFORD - 1	GOODINGS GROVE	345	345	SP	9.86		1	2-1277 ACAR, 2156 ACSR, 2-1033.5 ACSS/TW
62	1311 CRAWFORD - 2	GOODINGS GROVE	345	345	ST	10.58			2156 ACSR
63	1312 CRAWFORD - 1	GOODINGS GROVE	345	345	SP	0.33	9.62	1	2-1277 ACAR, 2156 ACSR, 2338 ACAR
64	1312 CRAWFORD - 2	GOODINGS GROVE	345	345	ST	0.05	10.53		2156 ACSR
65	1625 WAUKEGAN	NORTHBROOK 159	345	345	SP	0.26	21.47	1	2156 ACSR
66	1626 WAUKEGAN	NORTHBROOK 159	345	345	SP	21.78		1	2156 ACSR
67	2001 BRAIDWOOD - 1	E. FRANKFORT	345	345	ST	7.88		1	2-1277 ACAR
68	2001 BRAIDWOOD - 2	E. FRANKFORT	345	345	SP	28.08			2-1277 ACAR
69	2002 BRAIDWOOD - 1	DAVIS CREEK	345	345	ST	2.49		1	2156 ACSR
70	2002 BRAIDWOOD - 2	DAVIS CREEK	345	345	SP	20.50			2156 ACSR
71	2003 BRAIDWOOD - 1	E. FRANKFORT	345	345	ST	0.42	7.43	1	2-1277 ACAR
72	2003 BRAIDWOOD - 2	E. FRANKFORT	345	345	SP		28.08		2-1277 ACAR
73	2004 BRAIDWOOD - 1	DAVIS CREEK	345	345	ST	0.14	2.34	1	2156 ACSR
74	2004 BRAIDWOOD - 2	DAVIS CREEK	345	345	SP		20.50		2156 ACSR
75	2101 KINCAID	LANESVILLE (AMEREN)	345	345	ST	19.84		1	2-1277 ACAR
76	2102 KINCAID - 1	LATHAM (AMEREN)	345	345	ST	31.14		1	2-1277 ACAR
77	2102 KINCAID - 2	LATHAM (AMEREN)	345	345	SP	0.06			2-1277 ACAR
78	2105 KINCAID - 1	PANA	345	345	WH	25.94		1	2338 ACAR
79	2105 KINCAID - 2	PANA	345	345	ST	0.30			2338 ACAR
80	2105 KINCAID - 3	PANA	345	345	SP	0.15			2338 ACAR
81	2107 MT. PULASKI - 1	LANESVILLE (AMEREN)	345	345	SP	0.95		1	2-1277 ACAR
82	2107 MT. PULASKI - 2	LANESVILLE (AMEREN)	345	345	ST	7.23			2-1277 ACAR
83	2218 ZION	WAUKEGAN	345	345	SP	5.28		1	2156 ACSR
84	2219 ZION	WAUKEGAN	345	345	SP	0.33	4.94	1	2156 ACSR
85	2221 ZION - 1	ATC	345	345	ST	4.89		1	2156 ACSR
86	2221 ZION - 2	ATC	345	345	SP	2.96			2156 ACSR
87	2222 ZION - 1	ATC	345	345	ST		3.02	1	2338 ACAR
88	2222 ZION - 2	ATC	345	345	SP	0.87	1.94		2338 ACAR
89	2222 ZION - 3	ATC	345	345	ST		1.87		2156 ACSR
90	2222 ZION - 4	ATC	345	345	SP		0.15		2156 ACSR
91	2223 ZION - 1	ZION E.C.	345	345	SP	0.15		1	2156 ACSR
92	2223 ZION - 2	ZION E.C.	345	345	ST	3.04			2338 ACAR
93	2223 ZION - 3	ZION E.C.	345	345	SP	2.79			2338 ACAR
94	2224 ZION - 1	LIBERTYVILLE	345	345	ST	0.25	15.20	1	2338 ACAR
95	2224 ZION - 2	LIBERTYVILLE	345	345	SP	0.87	1.92		2338 ACAR
96	2224 ZION - 3	LIBERTYVILLE	345	345	SP		0.26		2156 ACSR
97	2310 COLLINS - 1	KENDALL CO.	345	345	SP	0.20		1	2156 ACSR
98	2310 COLLINS - 2	KENDALL CO.	345	345	ST	15.18			2156 ACSR
99	2311 COLLINS - 1	DRESDEN	345	345	SP	0.56		1	2156 ACSR
100	2311 COLLINS - 2	DRESDEN	345	345	ST	2.05	9.48		2156 ACSR
101	2912 JOLIET	LOCKPORT	345	345	ST	12.71		1	2156 ACSR
102	2913 JOLIET	LOCKPORT	345	345	ST	0.07	12.65	1	2156 ACSR
103	4620 DESPLAINES 46	PROSPECT HTS, 117	345	345	ST	0.62	4.00	1	2156 ACSR
104	4621 DESPLAINES - 1	GOLF MILL	345	345	ST	3.38		1	2156 ACSR
105	4621 DESPLAINES - 2	GOLF MILL	345	345	SP	0.18			2156 ACSR
106	4622 DESPLAINES - 1	GOLF MILL	345	345	ST		3.28	1	2156 ACSR
107	4622 DESPLAINES - 2	GOLF MILL	345	345	SP	0.05	0.15		2156 ACSR
108	6607 EAST FRANKFORT - 1	CRETE E.C.	345	345	SP	0.09		1	2156 ACSR
109	6607 EAST FRANKFORT - 2	CRETE E.C.	345	345	SP	0.37			1414 PE ACSR
110	6607 EAST FRANKFORT - 3	CRETE E.C.	345	345	ST	12.22			1414 PE ACSR
111	6608 EAST FRANKFORT - 1	UNIVERSITY PARK N. E.C.	345	345	SP	0.08		1	2156 ACSR
112	6608 EAST FRANKFORT - 2	UNIVERSITY PARK N. E.C.	345	345	SP	0.13			1414 ACSR
113	6608 EAST FRANKFORT - 3	UNIVERSITY PARK N. E.C.	345	345	ST	0.09	5.11		1414 ACSR
114	8001 PONTIAC MIDPOINT - 1	MCLEAN	345	345	ST	10.33		1	2-1277 ACAR
115	8001 PONTIAC MIDPOINT - 2	MCLEAN	345	345	SP	0.06
116	8002 PONTIAC MIDPOINT - 1	BLUE MOUND	345	345	ST	20.13		1	2-1277ACAR
117	8002 PONTIAC MIDPOINT - 2	BLUE MOUND	345	345	SP	7.22			2-1277ACAR
118	8012 PONTIAC MIDPOINT - 1	LORETTO	345	345	SP	0.17		1	2-1277ACAR
119	8012 PONTIAC MIDPOINT - 2	LORETTO	345	345	ST	11.32			2-1277ACAR
120	8014 DRESDEN	PONTIAC MIDPOINT	345	345	ST	43.28		1	2-1277 ACAR
121	8823 SKOKIE 88 - 1	GOLF MILL	345	345	SP	0.22		1	2156 ACSR
122	8823 SKOKIE 88 - 2	GOLF MILL	345	345	ST	4.43			2156 ACSR
123	8824 SKOKIE 88 - 1	GOLF MILL	345	345	SP	0.06	0.16	1	2156 ACSR
124	8824 SKOKIE 88 - 2	GOLF MILL	345	345	ST	0.02	4.48		2156 ACSR
125	9203 MCLEAN - 1	BROKAW (AMEREN)	345	345	SP	0.77		1	2-1277 ACAR
126	9203 MCLEAN - 2	BROKAW (AMEREN)	345	345	ST	20.03			2-1277 ACAR
127	9503 CHESTNUT - 1	LATHAM (AMEREN)	345	345	ST	5.83		1	2-1277 ACAR
128	9503 CHESTNUT - 2	LATHAM (AMEREN)	345	345	SP	0.27			2-1277 ACAR
129	9515 CHESTNUT - 1	BLUEMOUND	345	345	ST	34.74		1	2-1277 ACAR
130	9515 CHESTNUT - 2	BLUEMOUND	345	345	SP	0.26			2-1277 ACAR
131	9806 NEVADA - 1	GOODINGS GROVE	345	345	SP	0.17	0.39	1	2-1277 ACAR, 2156
132	9806 NEVADA - 2	GOODINGS GROVE	345	345	ST	0.18	55.68		2-1277 ACAR, 2338
133	10111 ITASCA	DESPLAINES 46	345	345	ST	9.01		1	2156 ACSR
134	10112 ITASCA	DESPLAINES 46	345	345	ST	0.41	8.67	1	2156 ACSR
135	10321 LISLE	LOMBARD	345	345	ST	8.68		1	2156 ACSR
136	10322 LISLE - 1	LOMBARD	345	345	ST	0.38	8.47	1	2156 ACSR
137	10322 LISLE - 2	LOMBARD	345	345	SP	0.17			2156 ACSR
138	10801 LOCKPORT	LOMBARD	345	345	ST	12.69		1	2156 ACSR
139	10802 LOCKPORT - 1	LOMBARD	345	345	ST	0.10	12.37	1	2156 ACSR
140	10802 LOCKPORT - 2	LOMBARD	345	345	SP	0.17			2156 ACSR
141	10803 LOCKPORT - 1	MCCOOK	345	345	ST	19.05		1	2338 ACAR,2156 ACSR
142	10803 LOCKPORT - 2	MCCOOK	345	345	SP	0.43			2156 ACSR
143	10804 LOCKPORT - 1	MCCOOK	345	345	ST	0.21	18.92	1	2338 ACAR,2156 ACSR
144	10804 LOCKPORT - 2	MCCOOK	345	345	SP		0.43		2156 ACSR
145	10805 LOCKPORT - 1	KENDALL CO.	345	345	SP	16.71		1	T2-1113 ACSR
146	10806 LOCKPORT - 1	KENDALL CO.	345	345	SP	0.15	15.95	1	T2-1113 ACSR
147	10807 LOCKPORT	LOMBARD	345	345	SP	21.53		1	T2-1113 ACSR
148	(b) 10808 LOCKPORT - 1	ITASCA	345	345	SP	0.56	20.96	1	T2-1113 ACSR
149	10808 LOCKPORT - 2	ITASCA	345	345	ST	8.05			2156 ACSR
150	11119 ELECTRIC JUNCTION	AURORA E.C.	345	345	ST	0.43	1.00	1	2338 ACAR, 2156 ACSR
151	11120 ELECTRIC JUNCTION - 1	LOMBARD	345	345	ST		4.41	1	2156 ACSR
152	11120 ELECTRIC JUNCTION - 2	LOMBARD	345	345	ST	0.56	4.09		2338 ACAR
153	11120 ELECTRIC JUNCTION - 3	LOMBARD	345	345	ST		8.93		2335 ACAR
154	11124 ELECTRIC JUNCTION - 1	LOMBARD	345	345	ST	12.20		1	2335 ACAR
155	11124 ELECTRIC JUNCTION - 2	LOMBARD	345	345	ST	0.84			2156 ACSR
156	11124 ELECTRIC JUNCTION - 3	LOMBARD	345	345	ST	4.59			2338 ACAR
157	11126 ELECTRIC JUNCTION - 1	WAYNE	345	345	SP	0.45		1	2156 ACSR, 2338 ACAR
158	11126 ELECTRIC JUNCTION - 2	WAYNE	345	345	ST	13.33			2338 ACAR, 2156 ACSR
159	11212 WILTON CENTER - 1	LORETTO	345	345	SP	1.95		1	2-1277 ACAR
160	11212 WILTON CENTER - 2	LORETTO	345	345	ST	38.02			2-1277 ACAR
161	11601 GOODINGS GROVE - 1	EAST FRANKFORT	345	345	ST	10.53		1	2-1033.5ACSS/TW
162	11601 GOODINGS GROVE - 2	EAST FRANKFORT	345	345	ST	0.28			2-1033.5ACSS/TW
163	11602 GOODINGS GROVE - 1	EAST FRANKFORT	345	345	ST	0.03	10.50	1	2-1033.5ACSS/TW
164	11602 GOODINGS GROVE - 2	EAST FRANKFORT	345	345	SP	0.23			2-1033.5ACSS/TW
165	11604 GOODINGS GROVE	LOCKPORT	345	345	ST	9.02		1	2156 ACSR
166	11607 GOODINGS GROVE	BEDFORD PARK	345	345	ST	18.51		1	2156 ACSR
167	11608 GOODINGS GROVE	BEDFORD PARK	345	345	ST	0.15	18.43	1	2156 ACSR
168	11613 TAP	BLUE ISLAND	345	345	ST	0.05	7.59	1	2338 ACAR
169	11613 GOODINGS GROVE - 1	WILTON CENTER	345	345	SP	0.58	0.14		2156 ACSR, 2338 ACAR
170	11613 GOODINGS GROVE - 2	WILTON CENTER	345	345	ST	9.63	21.09		2338 ACAR
171	11614 GOODINGS GROVE - 1	WILTON CENTER	345	345	ST	30.60		1	2338 ACAR, 2-1277 ACAR
172	11614 GOODINGS GROVE - 2	WILTON CENTER	345	345	SP	0.70			2338 ACAR, 2156 ACSR
173	11614 TAP	BLUE ISLAND	345	345	ST	7.64			2338 ACAR
174	11617 GOODINGS GROVE - 1	LOCKPORT	345	345	ST	0.08	8.80	1	2156 ACSR
175	11617 GOODINGS GROVE - 2	LOCKPORT	345	345	SP	0.03	0.08		2156 ACSR
176	11620 GOODINGS GROVE - 1	ELWOOD	345	345	ST	0.33	17.50	1	2156 ACSR
177	11620 GOODINGS GROVE - 2	ELWOOD	345	345	SP	0.36	0.52		2156/T2-1113 ACSR
178	11622 GOODINGS GROVE - 1	ELWOOD	345	345	ST	17.85		1	2156 ACSR
179	11622 GOODINGS GROVE - 2	ELWOOD	345	345	SP	0.86			T2-1113,2156 ACSR
180	11723 PROSPECT HTS. 117	LIBERTYVILLE	345	345	ST	15.36		1	2156 ACSR
181	11724 PROSPECT HTS. 117	DES PLAINES TSS46	345	345	ST	4.57		1	2338 ACAR, 2156 ACSR
182	12002 LOMBARD	ITASCA	345	345	ST	0.22	7.95	1	2156 ACSR
183	12003 LOMBARD	ELMHURST	345	345	ST	7.98		1	2338 ACAR, 2-664.8 ACSS/TW
184	12004 LOMBARD	ELMHURST	345	345	ST	0.15	7.77	1	2156 ACSR, 2338 ACAR, 2-664.8 ACSS/TW
185	12005 LOMBARD	DESPLAINES	345	345	ST	0.32	16.78	1	2156 ACSR
186	12006 LOMBARD	DESPLAINES	345	345	ST	17.09		1	2156 ACSR
187	13817 SILVER LAKE - 1	PLEASANT VALLEY	345	345	ST		9.35	1	2156 ACSR
188	13817 SILVER LAKE - 2	PLEASANT VALLEY	345	345	SP	0.39			2156 ACSR
189	13821 SILVER LAKE - 1	LIBERTYVILLE	345	345	ST	0.59	16.89	1	2338 ACAR
190	13821 SILVER LAKE - 2	LIBERTYVILLE	345	345	SP	0.19			2156 ACSR
191	14321 WOLFS - 1	ELECTRIC JUNCTION	345	345	ST	6.29		1	2156 ACSR, 2338 ACAR
192	14321 WOLFS - 2	ELECTRIC JUNCTION	345	345	SP	0.19			2156 ACSR
193	14401 WAYNE - 1	SILVER LAKE	345	345	ST	0.24	19.41	1	2338 ACAR
194	14401 WAYNE - 2	SILVER LAKE	345	345	SP	0.11	0.29		2338 ACAR
195	14402 WAYNE - 1	TOLLWAY	345	345	ST	5.54		1	2338 ACAR, 2156 ACSR
196	14402 WAYNE - 2	TOLLWAY	345	345	SP	0.06			2156 ACSR
197	14419 WAYNE - 1	AURORA E.C.	345	345	ST	0.03	12.34	1	2338 ACAR
198	14419 WAYNE - 2	AURORA E.C.	345	345	SP	0.16			2156 ACSR, 2338 ACAR
199	15324 TAYLOR	FISK	345	345	SP	0.20		1	2156 ACSR
200	15423 LIBERTYVILLE - 1	ZION E.C.	345	345	ST	12.33		1	2156 ACSR
201	15423 LIBERTYVILLE - 2	ZION E.C.	345	345	SP	0.11			2156 ACSR
202	15424 LIBERTYVILLE	PROSPECT HTS, 117	345	345	ST	0.34	14.93	1	2338 ACAR, 2156 ACSR
203	15501 NELSON - 1	LEE COUNTY E.C.	345	345	ST	4.29		1	2338 ACAR
204	15501 NELSON - 2	LEE COUNTY E.C.	345	345	ST	8.63			2-1277 ACAR
205	15501 NELSON - 3	LEE COUNTY E.C.	345	345	SP	0.07			2-1277 ACAR
206	15502 NELSON - 1	ELECTRIC JUNCTION	345	345	ST	15.92		1	2-1033.5 ACSS/TW
207	15502 NELSON - 2	ELECTRIC JUNCTION	345	345	SH	4.65			2-1277 ACAR
208	15502 NELSON - 3	ELECTRIC JUNCTION	345	345	ST	52.61			2-1277 ACAR
209	15503 NELSON - 1	CORDOVA	345	345	ST	0.07	0.34	1	2-1033.5 ACSS/TW,
210	15503 NELSON - 2	CORDOVA	345	345	ST	39.23			2-1227 ACAR
211	15503 NELSON - 3	CORDOVA	345	345	SP	0.04			2-1277 ACAR
212	15504 NELSON	N.W. STEEL & WIRE	345	345	ST	5.76	2.15	1	2-1277 ACAR
213	15615 CHERRY VALLEY	WEMPLETOWN	345	345	ST	27.22		1	2156 ACSR
214	15616 CHERRY VALLEY - 1	SILVER LAKE	345	345	ST	39.55		1	2338 ACAR, 2156 ACSR
215	15616 CHERRY VALLEY - 2	SILVER LAKE	345	345	SP	0.98			T2-1113 ACSR
216	15925 NORTHBROOK	SKOKIE 88	345	345	SP	5.63		1	2156 ACSR
217	15926 NORTHBROOK	SKOKIE 88	345	345	SP	0.06	5.46	1	2156 ACSR
218	16703 PLANO - 1	ELECTRIC JUNCTION	345	345	ST	0.12	11.48	1	2156 ACSR
219	16703 PLANO - 2	ELECTRIC JUNCTION	345	345	SP		9.59		2156 ACSR
220	16704 PLANO - 1	ELECTRIC JUNCTION	345	345	ST	11.60		1	2156 ACSR
221	16704 PLANO - 2	ELECTRIC JUNCTION	345	345	SP	9.66			2156 ACSR
222	17101 WEMPLETOWN - 1	ATC INTERCONNECTION	345	345	ST	10.40		1	2156 ACSR
223	17101 WEMPLETOWN - 2	ATC INTERCONNECTION	345	345	SP	0.99			2156 ACSR
224	17102 WEMPLETOWN - 1	ATC INTERCONNECTION	345	345	ST	0.06	10.34	1	2156 ACSR
225	17102 WEMPLETOWN - 2	ATC INTERCONNECTION	345	345	SP		0.99		2156 ACSR
226	17701 BURNHAM - 1	BLUE ISLAND	345	345	ST	7.79		1	2338 ACAR
227	17701 BURNHAM - 2	BLUE ISLAND	345	345	ST	0.60			2156 ACSR
228	17702 BURNHAM	BLUE ISLAND	345	345	ST	0.10	8.13	1	2338 ACAR
229	17703 BURNHAM	NIPSCO	345	345	ST	8.51		1	2338 ACAR
230	17704 BURNHAM - 1	DAVIS CREEK	345	345	ST	17.49		1	2156 ACSR, T2-1113 ACSR, 2338 ACAR
231	17704 BURNHAM - 2	DAVIS CREEK	345	345	SP	32.36			2156 ACSR, T2-1113 ACSR
232	17705 BURNHAM	SHEFFIELD (NIPSCO)	345	345	ST	0.04	3.68	1	2338 ACAR
233	17723 BURNHAM - 1	STATE LINE	345	345	SP	0.05		1	2156 ACSR
234	17723 BURNHAM - 2	STATE LINE	345	345	ST	3.80			2156 ACSR
235	17723 STATE LINE - 1	TAYLOR	345	345	SP	8.84			2156 ACSR, 2-1277 ACAR
236	17723 STATE LINE - 2	TAYLOR	345	345	ST	0.13			2156 ACSR
237	17724 BURNHAM	STATE LINE	345	345	ST	0.20	3.71	1	2156 ACSR
238	17724 STATE LINE - 1	TAYLOR	345	345	SP	0.50	8.47		2156 ACSR, 2-1277 ACAR
239	17724 STATE LINE - 2	TAYLOR	345	345	ST		0.13		2156 ACSR
240	17907 DAVIS CREEK - 1	BLOOM	345	345	SP	0.14	8.22	1	2156 ACSR
241	17907 DAVIS CREEK - 2	BLOOM	345	345	SP		24.00		T2-1113 ACSR
242	17907 DAVIS CREEK - 3	BLOOM	345	345	ST	0.17	4.73		2156 ACSR
243	17907 DAVIS CREEK - 4	BLOOM	345	345	ST	0.06	0.17		T2-1113 ACSR
244	17908 BURNHAM	BLOOM	345	345	ST	0.25	12.17	1	2156 ACSR, 2338 ACAR
245	18502 TOLLWAY - 1	LIBERTYVILLE	345	345	ST	22.84		1	2338 ACAR
246	18502 TOLLWAY - 2	LIBERTYVILLE	345	345	ST	7.69			2156 ACSR
247	18502 TOLLWAY - 3	LIBERTYVILLE	345	345	SP	0.12			2338 ACAR
248	18502 TOLLWAY - 4	LIBERTYVILLE	345	345	SP	0.12			2156 ACSR
249	18806 MT. PULASKI - 1	DEER CREEK	345	345	SH	0.73		1	2-1277 ACAR
250	18806 MT. PULASKI - 2	DEER CREEK	345	345	ST	15.82			2-1277 ACAR
251	18806 MT. PULASKI - 3	DEER CREEK	345	345	SP	1.09			2-1277 ACAR
252	19601 KATYDID - 1	GOODINGS GROVE	345	345	SP	0.06		1	2-1277 ACAR, 2156
253	19601 KATYDID - 2	GOODINGS GROVE	345	345	ST	53.45			2-1277 ACAR, 2156
254	90907 DEER CREEK - 1	BROKAW (AMEREN)	345	345	SH	7.49		1	2-1277 ACAR
255	90907 DEER CREEK - 2	BROKAW (AMEREN)	345	345	ST	13.04			2-1277 ACAR
256	90907 DEER CREEK - 3	BROKAW (AMEREN)	345	345	SP	1.27			2-1277 ACAR
257	93505 KENDALL CO. - 1	DRESDEN	345	345	SP	0.38		1	2338 ACAR, 2156 A
258	93505 KENDALL CO. - 2	DRESDEN	345	345	ST		7.38		2338 ACAR, 2-1277
259	93913 MULBERRY - 1	MOLE CREEK	345	345	SP	0.47		1	2-1277 ACAR, 2156 ACSR
260	93913 MULBERRY - 2	MOLE CREEK	345	345	ST	57.28			2-1277 ACAR, 2338 ACAR
261	93915 MULBERRY - 1	TAZEWELL (CLICO)	345	345	SP	0.16	0.18	1	2156 ACSR
262	93915 MULBERRY - 2	TAZEWELL (CLICO)	345	345	ST	0.17	94.27		2-1277 ACAR, 2338 ACAR
263	97008 UNIVERSITY PK. E.C. - 1	I & M POWER	345	345	ST	4.57	7.03	1	1414 ACSR
264	97008 UNIVERSITY PK. E.C. - 2	I & M POWER	345	345	SP	0.62			1414 ACSR, 2156 A
265	94507 CRETE E.C. - 1	N.I.P.S.CO.	345	345	ST		4.54	1	1414 ACSR, 2156 A
266	94507 CRETE E.C. - 2	N.I.P.S.CO.	345	345	SP	0.42			1414 ACSR, 2156 A
267	345KV LINES
268	1309 FISK TERMINAL	WEST LOOP	345	345	UG	4.87			1600mm2 XLPE
269	15323 TAYLOR	WEST LOOP	345	345	UG	3.30		1	1600mm2 XLPE
270	15324 TAYLOR	FISK	345	345	UG	2.20			1600mm2 XLPE
271	17723X TAYLOR	GARFIELD	345	345	UG	6.08			2500KCMIL
272	17724Y TAYLOR - 1	GARFIELD	345	345	UG	6.08			2500KCMIL
273	17724X TAYLOR	GARFIELD	345	345	UG	6.11			1600mm2 XLPE
274	17724Y TAYLOR - 2	GARFIELD	345	345	UG	6.10			1600mm2 XLPE
275	138KV LINES OVERHEAD
276	2 STEAM PLANT ROAD - 1	TWOMBLY ROAD	138	138	WP	2.63		1	556.5 ACSR
277	2 STEAM PLANT ROAD - 2	TWOMBLY ROAD	138	138	SP	0.47			556.5 ACSR
278	4 STEAM PLANT ROAD	CARON ROAD	138	138	SP	0.06		1	556.5 ACSR
279	0108 LASALLE CO. - 1	SW TIE L-1205	138	138	SP	0.37		1	1113 ACSR, 664.8 ACSS/TW
280	0108 LASALLE CO. - 2	SW TIE L-1205	138	138	WP	2.95			664.8 ACSS, 477&1
281	0108 LASALLE CO. - 3	SW TIE L-1205	138	138	WH	0.30			664.8 ACSS/TW
282	0108 LASALLE CO. - 4	SW TIE L-1205	138	138	ST		12.89		300CU,477ACS
283	0108 TAP	SW TIE L-6102	138	138	WP	0.06			477 ACSR
284	0112 LASALLE CO.	KICKAPOO CREEK	138	138	SP	1.35			1113 ACSR, T2-555
285	0321 POWERTON - 1	TOULON	138	138	ST	42.21		1	477,1113 ACSR
286	0321 POWERTON - 2	TOULON	138	138	SP	0.65			1113 ACSR, 922
287	0703 STATE LINE	HEGEWISCH	138	138	ST	0.26	2.39	1	1113 ACSR
288	0703 TAP - 1	LTV STEEL	138	138	WP	0.07			477ACSR
289	0703 TAP - 2	RIVER E.C.	138	138	ST	0.39			477,636, 2-336.4A
290	0703 TAP - 3	RIVER E.C.	138	138	SP	1.87			477,636,
291	0704 STATE LINE - 1	RIVER E.C.	138	138	ST		1.15	1	336.4,477,636,111
292	0704 STATE LINE - 2	RIVER E.C.	138	138	SP	0.21	1.79		636, 1113ACSR
293	0704 STATE LINE - 3	RIVER E.C.	138	138	WP	0.16			1113 ACSR
294	0704 TAP - 1	TOWER AUTOMOTIVE	138	138	ST	0.10	0.16		1113 ACSR
295	0704 TAP - 2	TOWER AUTOMOTIVE	138	138	WP	0.11			1113 ACSR
296	0706 STATE LINE - 1	CALUMET	138	138	SP	1.28		1	1113,2156 ACSR
297	0706 STATE LINE - 2	CALUMET	138	138	ST	0.10			1113,2156 ACSR
298	0706 STATE LINE - 3	CALUMET	138	138	WP	0.07			1113 ACSR
299	0707 STATE LINE - 1	CALUMET	138	138	ST	0.59		1	750 CU / 1113,215
300	0707 STATE LINE - 2	CALUMET	138	138	SP		1.10		2156 ACSR
301	0707 TAP	TAP TO T-3030	138	138	ST	0.18			2156 ACSR
302	0708 STATE LINE - 1	CALUMET	138	138	ST	0.24	0.61	1	750 CU / 1113,215
303	0708 STATE LINE - 2	CALUMET	138	138	SP	0.12	0.99		2156 ACSR
304	0708 TAP - 1	HARBOR	138	138	ST	0.08			2156 ACSR
305	0708 TAP - 2	HARBOR	138	138	SP	0.21			2156 ACSR
306	0716 ILL-IND STATE LINE - 1	CALUMET	138	138	WP	0.09		1	1113 ACSR
307	0716 ILL-IND STATE LINE - 2	CALUMET	138	138	SP	0.24	1.07		2-1277.2 ACAR / 1
308	0716 ILL-IND STATE LINE - 3	CALUMET	138	138	ST		0.13		2156 ACSR
309	0901 JOLIET - 1	EAST FRANKFORT	138	138	ST		14.75	1	300CU/636,1113/66
310	0901 JOLIET - 2	EAST FRANKFORT	138	138	SP	0.08	0.30		300 CU
311	0901 TAP - 1	DAVIS CREEK	138	138	SP	19.52			2-556.5,1113 ACSR
312	0901 TAP - 2	DAVIS CREEK	138	138	SH	0.17			2-556.5 ACSR
313	0901 TAP - 3	DAVIS CREEK	138	138	SP		0.76		1113 ACSR
314	0901 TAP - 4	DAVIS CREEK	138	138	ST	0.06	0.47		1113 ACSR
315	0902 JOLIET - 1	EAST FRANKFORT	138	138	ST	3.83	11.24	1	477,1113 ACSR, 66
316	0902 JOLIET - 2	EAST FRANKFORT	138	138	SP	0.09			477 ACSR
317	0902 TAP - 1	DAVIS CREEK	138	138	WP	10.69			636 ACSR
318	0902 TAP - 2	DAVIS CREEK	138	138	WH	8.70			636 ACSR
319	0902 TAP - 3	DAVIS CREEK	138	138	SP	0.19	2.41		636,1113 ACSR
320	0902 TAP - 4	DAVIS CREEK	138	138	ST	0.06	0.63		1113 ACSR
321	0903 JOLIET - 1	DRESDEN	138	138	ST	0.24	7.67	1	1113 ACSR
322	0903 JOLIET - 2	DRESDEN	138	138	SP	0.49	6.94		1113 ACSR
323	0904 JOLIET - 1	DRESDEN	138	138	ST	0.33	9.22	1	300 CU / 1113 ACS
324	0904 JOLIET - 2	DRESDEN	138	138	WP	0.58			1113 ACSR
325	0904 JOLIET - 3	DRESDEN	138	138	SP	4.87	0.08		1113 ACSR
326	0905 JOLIET - 1	WILL COUNTY	138	138	ST	5.20	7.08	1	477, T2-556.5 ACSR, 763.0 ACCR/TW
327	0905 JOLIET - 2	WILL COUNTY	138	138	SP	2.65			T2-556.5 ACSR, 664.8 ACSS/TW
328	0905 TAP	JOLIET TR.# 79	138	138	WP	0.01			477 ACSR
329	0906 JOLIET - 1	WILL COUNTY	138	138	ST	7.86	7.88	1	477, 900, 1113, T2-556.5 ACSR, 664.8 ACSS/TW
330	0906 JOLIET - 2	WILL COUNTY	138	138	SP	0.82			T2-556.5 ACSR, 664.8 ACSS/TW
331	0907 JOLIET - 1	WOLFS	138	138	ST	2.85	15.60	1	300 CU / 1113 ACW
332	0907 JOLIET - 2	WOLFS	138	138	SP		0.08		1113 ACSR
333	0907 JOLIET - 3	WOLFS	138	138	WH		0.06		300 CU
334	0908 JOLIET - 1	SHOREWOOD	138	138	ST	0.34	7.79	1	1113 ACSR
335	0908 JOLIET - 2	SHOREWOOD	138	138	WP	0.08			1113 ACSR
336	0908 JOLIET - 3	SHOREWOOD	138	138	SP	0.13	5.64		1113 ACSR
337	1106 FISK	QUARRY	138	138	SP	0.21		1	1113 ACSR
338	1108 FISK	QUARRY	138	138	SP	0.17		1	1113ACSR
339	1205 DRESDEN - 1	SW TIE L-0108	138	138	ST	8.30	8.20	1	300 CU / 477,1113
340	1205 DRESDEN - 2	SW TIE L-0108	138	138	WP	0.07			477,1113 ACSR
341	1205 TAP	MAZON	138	138	SP	0.09			477 ACSR
342	1206 DRESDEN - 1	CHANNAHON WEST	138	138	ST	2.55	3.75		477,1113 ACSR
343	1206 DRESDEN - 2	CHANNAHON WEST	138	138	WP	0.28			1113 ACSR
344	1206 TAP	EQUISTAR	138	138	SP	0.11	0.09
345	1207 DRESDEN - 1	WILMINGTON	138	138	WP	13.05		1	636 ACSR
346	1207 DRESDEN - 2	WILMINGTON	138	138	WH	0.14			636 ACSR
347	1210 DRESDEN - 1	CARGO COURT	138	138	WP	2.00		1	1113 AA / 1113 AC
348	1210 DRESDEN -2	CARGO COURT	138	138	WH	2.94			1113 AA / 1113 AC
349	1306 RIDGELAND - 1	CRAWFORD	138	138	ST	0.05	0.73	1	1113 ACSR
350	1306 RIDGELAND - 2	CRAWFORD	138	138	SP	0.36	2.50		1113 ACSR
351	1315 RIDGELAND - 1	CRAWFORD	138	138	ST	0.16	1.20	1	900, 1113 ACSR
352	1315 RIDGELAND - 2	CRAWFORD	138	138	SP	0.27	2.66		1113 ACSR
353	1315 RIDGELAND - 3	CRAWFORD	138	138	WP	0.03			900 ACSR
354	1321 CRAWFORD - 1	CONGRESS	138	138	SP	0.31	0.40	1	1113 ACSR
355	1321 CRAWFORD - 2	CONGRESS	138	138	ST	0.28	4.02		1113 ACSR
356	1322 CRAWFORD - 1	BEDFORD PARK	138	138	ST	0.29	3.13	1	1113 ACSR
357	1322 CRAWFORD - 2	BEDFORD PARK	138	138	SP	0.02	4.31		2-556.5,1113 ACSR
358	1322 CRAWFORD - 3	BEDFORD PARK	138	138	WP	0.05			1113 ACSR
359	1323 CRAWFORD - 1	CONGRESS	138	138	SP	0.67		1	1113 ACSR
360	1323 CRAWFORD - 2	CONGRESS	138	138	ST	4.44			1113 ACSR
361	1324 CRAWFORD - 1	BEDFORD PARK	138	138	ST	0.28	2.82	1	1113 ACSR
362	1324 CRAWFORD - 2	BEDFORD PARK	138	138	SP	0.02	4.26		2-556.5,1113 ACSR
363	1324 CRAWFORD - 3	BEDFORD PARK	138	138	WP	0.41			1113 ACSR
364	1404 POWERTON	JUNCTION WITH AMEREN	138	138	WH	0.37			477 ACSR
365	1603 WAUKEGAN - 1	SW TIE L-4203	138	138	ST	0.28	14.55	1	300 CU / 477,1113
366	1603 WAUKEGAN - 2	SW TIE L-4203	138	138	SP	0.32	0.34		300 CU / 477,1113
367	1604 WAUKEGAN - 1	LIBERTYVILLE	138	138	ST	0.24	13.45	1	1113 ACSR
368	1604 WAUKEGAN - 2	LIBERTYVILLE	138	138	SP	0.10	0.50		1113 ACSR
369	1604 WAUKEGAN - 3	LIBERTYVILLE	138	138	WH	0.05			1113 ACSR
370	1605 WAUKEGAN - 1	HIGHLAND PARK	138	138	ST	15.80		1	1113 ACSR
371	1605 WAUKEGAN - 2	HIGHLAND PARK	138	138	WP	0.35			1113 ACSR
372	1605 WAUKEGAN - 3	HIGHLAND PARK	138	138	SP	0.98			1113,2156 ACSR
373	1606 WAUKEGAN - 1	HIGHLAND PARK	138	138	ST	0.10	15.80	1	1113 ACSR
374	1606 WAUKEGAN - 2	HIGHLAND PARK	138	138	WP	0.30			1113 ACSR
375	1606 WAUKEGAN - 3	HIGHLAND PARK	138	138	SP	0.53	0.48		1113,2156 ACSR
376	1607 WAUKEGAN - 1	SW TIE L-4202	138	138	ST	0.32	14.76	1	300CU/1113ACSR/
377	1607 WAUKEGAN - 2	SW TIE L-4202	138	138	SP	0.19	0.34		300CU/1113ACSR/
378	1607 TAP	ROUND LAKE	138	138	SP	0.03			477 ACSR
379	1608 WAUKEGAN - 1	LIBERTYVILLE	138	138	ST	0.23	13.47	1	1113 ACSR
380	1608 WAUKEGAN - 2	LIBERTYVILLE	138	138	SP	0.09	0.50		1113 ACSR
381	1608 WAUKEGAN - 3	LIBERTYVILLE	138	138	WH	0.05			1113 ACSR
382	1609 WAUKEGAN - 1	ZION TDC 282	138	138	WH	5.54		1	1113 ACSR
383	1609 WAUKEGAN - 2	ZION TDC 282	138	138	WP	0.15			900,1113 ACSR
384	1609 WAUKEGAN - 3	ZION TDC 282	138	138	ST	4.41	1.79		1113 ACSR
385	1609 WAUKEGAN - 4	ZION TDC 282	138	138	SP	0.31			1113 ACSR
386	1802 WILL COUNTY - 1	ARGONNE	138	138	ST	0.45	7.08	1	1113 ACSR
387	1802 WILL COUNTY - 2	ARGONNE	138	138	SP	0.28	0.43		1113 ACSR
388	1802 WILL COUNTY - 3	ARGONNE	138	138	WP	0.07			1113 ACSR
389	1803 WILL COUNTY - 1	BOLINGBROOK BREAKER	138	138	ST	2.50		1	2-556.5 ACSR
390	1803 WILL COUNTY - 2	BOLINGBROOK BREAKER	138	138	SP	4.00			2-556.5,1113 ACSR
391	1804 WILL COUNTY - 1	WOLFS	138	138	ST	5.44	9.07	1	477,900,1113
392	1804 WILL COUNTY - 2	WOLFS	138	138	SP	0.08			1113 ACSR
393	1807 WILL COUNTY - 1	ARGONNE NAT'L LAB	138	138	ST	0.50	7.07	1	1113 ACSR
394	1807 WILL COUNTY - 2	ARGONNE NAT'L LAB	138	138	WP	0.04			1113 ACSR
395	1807 WILL COUNTY - 3	ARGONNE NAT'L LAB	138	138	SP		0.43		1113 ACSR
396	1808 WILL COUNTY - 1	GOODINGS GROVE	138	138	ST	0.57	8.92	1	900 ACSR
397	1808 WILL COUNTY - 2	GOODINGS GROVE	138	138	SP	0.13	0.55		900 ACSR
398	1809 WILL COUNTY - 1	NORMANTOWN	138	138	ST	0.47	0.94	1	1033.5ACSS/TW, 2-
399	1809 WILL COUNTY - 2	NORMANTOWN	138	138	SP	0.03	2.22		2-566.5, 2156ACSR
400	1811 WILL COUNTY - 1	GOODINGS GROVE	138	138	ST	0.91	8.49	1	900 ACSR
401	1811 WILL COUNTY - 2	GOODINGS GROVE	138	138	SP		0.60		900 ACSR
402	4202 SILVER LAKE - 1	SW TIE L-1607	138	138	ST	0.37	13.68	1	300 CU / 477,1113
403	4202 SILVER LAKE - 2	SW TIE L-1607	138	138	SP	0.14	0.13		1113 ACSR
404	4203 SILVER LAKE - 1	SW TIE L-1603	138	138	ST	10.00	4.00	1	477,1113 ACSR
405	4203 SILVER LAKE - 2	SW TIE L-1603	138	138	SP	0.18	0.13		477 ACSR
406	4203 SILVER LAKE - 3	SW TIE L-1603	138	138	WH	0.07			1113 ACSR
407	4203 TAP	ROUND LAKE	138	138	SP	0.05			1113 ACSR
408	4605 DESPLAINES 46 - 1	ELK GROVE	138	138	ST	0.17	4.14	1	1113 ACSR
409	4605 DESPLAINES 46 - 2	ELK GROVE	138	138	SP	0.20			1113,2156 ACSR
410	4609 DESPLAINES 46 - 1	DESPLAINES 198	138	138	WP	0.12	3.06	1	1113 ACSR, 664.8
411	4609 DESPLAINES 46 - 2	DESPLAINES 198	138	138	SP	0.23			1113 ACSR
412	4606 DESPLAINES 46 - 1	ELK GROVE	138	138	ST		4.08	1	1113 ACSR
413	4606 DESPLAINES 46 - 2	ELK GROVE	138	138	SP	0.38			1113 ACSR
414	4608 DESPLAINES 46 - 1	DESPLAINES 198	138	138	WP	0.32	3.03	1	1113 ACSR, 664.8
415	4608 DESPLAINES 46 - 2	DESPLAINES 198	138	138	WH	0.07			1113 ACSR
416	4608 DESPLAINES 46 - 3	DESPLAINES 198	138	138	SP	0.10			1113 ACSR
417	4610 DESPLAINES 46 - 1	GOLF MILL	138	138	ST	0.06	3.46	1	1113 ACSR
418	4610 DESPLAINES 46 - 2	GOLF MILL	138	138	SP	0.05			1113 ACSR
419	4610 DESPLAINES 46 - 3	GOLF MILL	138	138	WP	0.16			1113 ACSR
420	4611 DESPLAINES 46 - 1	GOLF MILL	138	138	ST		3.47	1	1113 ACSR
421	4611 DESPLAINES 46 - 2	GOLF MILL	138	138	SP	0.04			1113 ACSR
422	4611 DESPLAINES 46 - 3	GOLF MILL	138	138	WP	0.30			1113 ACSR
423	5103 MCCOOK - 1	WILLOW SPRINGS	138	138	ST	0.42	4.86	1	1113 ACSR
424	5103 MCCOOK - 2	WILLOW SPRINGS	138	138	SP	0.09			1113 ACSR
425	5103 MCCOOK - 3	WILLOW SPRINGS	138	138	WP	0.09			1113 ACSR
426	5103 TAP - 1	BEDFORD PARK	138	138	SP	0.96			1113 ACSR
427	5103 TAP - 2	BEDFORD PARK	138	138	ST	4.20			477,1113 ACSR
428	5104 MCCOOK - 1	BEDFORD PARK	138	138	ST	2.50		1	900,1113 ACSR, 10
429	5104 MCCOOK - 2	BEDFORD PARK	138	138	SP	1.06	0.96		1113 ACSR, 1033.5
430	5104 MCCOOK - 3	BEDFORD PARK	138	138	WP	1.94			900 ACSR
431	5104 MCCOOK - 4	BEDFORD PARK	138	138	WH	1.10			900 ACSR
432	5104 TAP - 1	ARGONNE LABS	138	138	SP	8.33			900 ACSR
433	5104 TAP - 2	ARGONNE LABS	138	138	WP	0.10			1113 ACSR
434	5105 RIDGELAND	MCCOOK	138	138	ST	0.33	1.78	1	900,1113 ACSR
435	5107 MCCOOK - 1	RIDGELAND	138	138	ST	0.40	1.80	1	1033.5ACSS/TW, 2-
436	5107 MCCOOK - 2	RIDGELAND	138	138	SP	0.20			1033.5 ACSS/TW
437	5117 MCCOOK - 1	BELLWOOD	138	138	SP	6.78		1	1113 AA / 1113 AC
438	5117 MCCOOK - 2	BELLWOOD	138	138	ST	1.38			1113 AA / 1113 AC
439	5118 MCCOOK - 1	BELLWOOD	138	138	SP	0.02	6.33	1	1113 AA / 1113 AC
440	5118 MCCOOK - 2	BELLWOOD	138	138	ST	0.12	1.60		1113 AA / 1113 AC
441	6101 STREATOR - 1	PUTNAM (AMEREN)	138	138	ST	29.62		1	300 CU / 300,477 ACSR
442	6101 STREATOR - 2	PUTNAM (AMEREN)	138	138	SP	0.94			477, 2-556.5 ACSR
443	6102 STREATOR - 1	KICKAPOO CREEK	138	138	ST	0.11	9.34	1	477 ACSR, 664.8 ACSS/TW
444	6102 STREATOR - 2	KICKAPOO CREEK	138	138	WP	2.07			636 ACSR, 477
445	6102 STREATOR - 3	KICKAPOO CREEK	138	138	WH	11.37			477 ACSR
446	6102 STREATOR - 4	KICKAPOO CREEK	138	138	SP	0.01			1113 KCMIL
447	6102 TAP	MARSEILLES S.S.	138	138	WP	0.01			477 ACSR
448	6603 EAST FRANKFORT - 1	MATTESON	138	138	ST	0.10	5.36	1	300 CU / 477,1113
449	6603 EAST FRANKFORT - 2	MATTESON	138	138	SP	0.54			1113 ACSR,664.8 A
450	6603 EAST FRANKFORT - 3	MATTESON	138	138	WP	0.07			1113 ACSR
451	6604 EAST FRANKFORT - 1	MATTESON	138	138	ST	0.03	5.82	1	477, 664.8 ACSS/T
452	6604 EAST FRANKFORT - 2	MATTESON	138	138	SP	0.13			1113 ACSR
453	6604 EAST FRANKFORT - 3	MATTESON	138	138	WP	0.11			1113 ACSR
454	6605 EAST FRANKFORT - 1	UNIVERSITY PARK	138	138	SP	0.05		1	1113 ACSR
455	6605 EAST FRANKFORT - 2	UNIVERSITY PARK	138	138	ST		5.34		1113 ACSR
456	6606 EAST FRANKFORT - 1	UNIVERSITY PARK	138	138	ST		5.34	1	1113 ACSR
457	6606 EAST FRANKFORT - 2	UNIVERSITY PARK	138	138	SP	0.04			1113 ACSR
458	6721 CONGRESS - 1	ROCKWELL	138	138	SP	0.01	0.25	1	1113 ACSR
459	6721 CONGRESS - 2	ROCKWELL	138	138	ST	0.01	0.94		1113 ACSR
460	6721 CONGRESS - 3	ROCKWELL	138	138	WP		0.08		1113 ACSR
461	6723 CONGRESS - 1	ROCKWELL	138	138	SP	0.03	0.36	1	1113 ACSR
462	6723 CONGRESS - 2	ROCKWELL	138	138	ST		0.91		1113 ACSR
463	7305 CHICAGO HTS. - 1	BLOOM	138	138	SP	0.11		1	1113 ACSR
464	7305 CHICAGO HTS. - 2	BLOOM	138	138	ST	0.32			1113 ACSR
465	7305 CHICAGO HTS. - 3	BLOOM	138	138	WP	0.75	1.29		1113 ACSR
466	7306 CHICAGO HTS. - 1	BLOOM	138	138	SP	0.05		1	1113 ACSR
467	7306 CHICAGO HTS. - 2	BLOOM	138	138	ST	2.19			1113 ACSR
468	7306 CHICAGO HTS. - 3	BLOOM	138	138	WP	0.24			1113 ACSR
469	7307 CHICAGO HTS. - 1	BURNHAM	138	138	ST	1.41	4.39	1	1113,2338 ACSR
470	7307 CHICAGO HTS. - 2	BURNHAM	138	138	SP	0.15	0.18		1113 ACSR
471	7307 CHICAGO HTS. - 3	BURNHAM	138	138	WP	3.74			1113 ACSR
472	7411 KEWANEE	AMEREN KEEMIN	138	138	ST		6.91	1	477 ACSR
473	7413 KEWANEE - 1	CRESCENT RIDGE	138	138	ST	0.18	15.23	1	300 CU / 477 ACSR
474	7413 KEWANEE - 2	CRESCENT RIDGE	138	138	SP	0.02			1113 ACSR
475	7421 KEWANEE - 1	TOULON	138	138	ST	11.70		1	477 ACSR
476	7421 KEWANEE - 2	TOULON	138	138	SP	0.04			1113 ACSR
477	7423 KEWANEE - 1	EDWARD STA (CILCO)	138	138	ST	0.18	50.04	1	477 ACSR
478	7423 KEWANEE - 2	EDWARD STA (CILCO)	138	138	SP	0.47	0.01		1113 ACSR
479	7611 BLUE ISLAND - 1	WILDWOOD	138	138	ST	0.13	3.81	1	900 ACSR
480	7611 BLUE ISLAND - 2	WILDWOOD	138	138	SP		0.13		900 ACSR
481	7612 BLUE ISLAND - 1	WILDWOOD	138	138	ST	0.20	3.74	1	900,1113 ACSR
482	7612 BLUE ISLAND - 2	WILDWOOD	138	138	SP	0.01	0.13		900 ACSR
483	7615 BLUE ISLAND - 1	SW TIE L-11603	138	138	ST	3.44	0.36	1	1113 ACSR
484	7616 BLUE ISLAND - 2	SW TIE L-11609	138	138	ST	0.34	3.43	1	1113 ACSR
485	7713 MAZON - 1	CORBIN (AMEREN)	138	138	ST	34.42	0.00	1	300 CU, 477 ACSR
486	7713 MAZON - 2	CORBIN (AMEREN)	138	138	SP	0.15	0.00		1113 ACSR
487	7719 MAZON - 1	CHANNAHON WEST	138	138	ST	5.73	4.29	1	3000 CU/1113
488	7719 MAZON - 2	CHANNAHON WEST	138	138	SP	0.07			1113 ACSR
489	7719 MAZON - 3	CHANNAHON WEST	138	138	WP	0.07			266.5 ACSR
490	7719 TAP	SW TIE L-7413	138	138	WP	0.07			300 CU
491	7902 SPAULDING - 1	TOLLWAY	138	138	ST	0.22	3.79	1	1113,2156 ACSR
492	7902 SPAULDING - 2	TOLLWAY	138	138	SP	0.03	0.15		2156 ACSR
493	7903 SPAULDING - 1	TOLLWAY	138	138	ST	0.13	3.79	1	1113,2156 ACSR
494	7903 SPAULDING - 2	TOLLWAY	138	138	SP	0.10	0.15		1113 ACSR
495	7903 SPAULDING - 3	TOLLWAY	138	138	WP	0.09			1113 ACSR
496	7910 SPAULDING - 1	WAYNE	138	138	ST	0.08	1.23	1	1113 ACSR
497	7910 SPAULDING - 2	WAYNE	138	138	SP		0.16		1113,2156 ACSR
498	7910 SPAULDING - 3	WAYNE	138	138	WP	0.25			1113 ACSR
499	7915 SPAULDING - 1	WAYNE	138	138	SP	0.44		1	1113,2156 ACSR
500	7915 SPAULDING - 2	WAYNE	138	138	ST	0.02	1.19		1113 ACSR
501	8221 CROSBY - 1	ROCKWELL	138	138	ST	0.08	1.53	1	1113 ACSR
502	8221 CROSBY - 2	ROCKWELL	138	138	SP	0.01	0.29		1113 ACSR
503	8223 CROSBY - 1	ROCKWELL	138	138	ST	0.08	1.51	1	1113 ACSR
504	8223 CROSBY - 2	ROCKWELL	138	138	SP	0.02	0.29		1113 ACSR
505	8607 DAVIS CREEK - 1	WILMINGTON	138	138	SP	0.14	1.83	1	1113 ACSR
506	8607 DAVIS CREEK - 2	WILMINGTON	138	138	ST		0.68		1113 ACSR
507	8607 DAVIS CREEK - 3	WILMINGTON	138	138	WP	21.58	0.24		636 ACSR, 113 ACSR
508	8801 SKOKIE 88 - 1	GOLF MILL	138	138	ST		4.41	1	1113 ACSR
509	8801 SKOKIE 88 - 2	GOLF MILL	138	138	SP	0.03			1113 ACSR
510	8801 SKOKIE 88 - 3	GOLF MILL	138	138	WP	0.20			1113 ACSR
511	8802 SKOKIE 88 - 1	GOLF MILL	138	138	ST	0.07	4.27	1	1113 ACSR
512	8802 SKOKIE 88 - 2	GOLF MILL	138	138	SP	0.04			1113 ACSR
513	8802 SKOKIE 88 - 3	GOLF MILL	138	138	WP	0.15			1113 ACSR
514	8803 SKOKIE 88 - 1	DEVON	138	138	ST	0.09	1.78	1	900,1113 ACSR
515	8803 SKOKIE 88 - 2	DEVON	138	138	SP	0.15	1.45		1113 ACSR
516	8803 SKOKIE 88 - 3	DEVON	138	138	WP	0.17			900,1113 ACSR
517	8805 SKOKIE 88 - 1	NORTHBROOK 159	138	138	ST	3.95		1	1113 ACSR
518	8805 SKOKIE 88 - 2	NORTHBROOK 159	138	138	SP	0.85	0.73		1113 ACSR
519	8806 SKOKIE 88 - 1	NORTHBROOK 159	138	138	ST	0.28	4.33	1	1113 ACSR
520	8806 SKOKIE 88 - 2	NORTHBROOK 159	138	138	SP	0.71	0.23		1113 ACSR
521	8809 SKOKIE 88 - 1	DEVON	138	138	ST	0.09	1.86	1	1113 ACSR
522	8809 SKOKIE 88 - 2	DEVON	138	138	SP	0.27	1.42		1113 ACSR
523	8810 SKOKIE 88 - 1	DEVON	138	138	ST	3.49		1	1113 ACSR
524	8810 SKOKIE 88 - 2	DEVON	138	138	WP	0.19			1113 ACSR
525	8603 DAVIS CREEK - 1	BRADLEY	138	138	ST	0.33		1	1113 ACSR
526	8603 DAVIS CREEK - 2	BRADLEY	138	138	SP	6.00			2-556.5,1113 ACSR
527	8603 TAP - 1	CSL BEHRING	138	138	SP	0.59			1113 ACSR
528	8605 DAVIS CREEK - 1	BRADLEY	138	138	SP	2.15	2.51	1	2-556.5,1113 ACSR
529	8605 DAVIS CREEK - 2	BRADLEY	138	138	WP	2.94			1113 ACSR
530	8605 TAP - 1	CSL BEHRING	138	138	SP	0.12	0.51		2-556.5,1113 ACSR
531	9117 CARGO COURT - 1	SHOREWOOD	138	138	WH	3.21		1	1113 AA
532	9117 CARGO COURT - 2	SHOREWOOD	138	138	SP	0.49	4.24		1113 ACSR
533	10117 ITASCA - 1	TONNE	138	138	SP	0.12	0.43	1	2156 ACSR
534	10117 ITASCA - 2	TONNE	138	138	ST		1.32		1033.5 ACSS/TW
535	10118 ITASCA - 1	TONNE	138	138	SP	0.13	0.44	1	2156 ACSR
536	10118 ITASCA - 2	TONNE	138	138	ST		1.29		1033.5 ACSS/TW
537	10301 LISLE - 1	LOMBARD	138	138	SP	0.53	7.93	1	1113,2156,2-1113A
538	10301 LISLE - 2	LOMBARD	138	138	ST	0.32			900 ACSR
539	10301 LISLE - 3	LOMBARD	138	138	WP	0.06			1113, 2156 ACSR
540	10302 LISLE - 1	LOMBARD	138	138	ST	0.18		1	900 ACSR
541	10302 LISLE - 2	LOMBARD	138	138	SP	0.57	8.06		1113,2156,2-1113A
542	10314 LISLE	BOLINGBROOK	138	138	SP	0.16	7.41	1	1113, 2-556.6ACSR
543	10319 LISLE - 1	BOLINGBROOK	138	138	WP	0.03		1	1113ACSR
544	10319 LISLE - 2	BOLINGBROOK	138	138	SP		7.54		1113, 2-556.6ACSR
545	10714 DIXON - 1	MCGIRR ROAD	138	138	ST	1.57		1	763.0ACSR/TW,
546	10714 DIXON - 2	MCGIRR ROAD	138	138	SP	23.42			763.0ACSR/TW, 2-5
547	10721 DIXON - 1	STILLMAN VALLEY	136	138	ST	10.49	3.94	1	1113 ACSR, 2156
548	10721 DIXON - 2	STILLMAN VALLEY	138	138	SP	1.53			1113 ACSR, 2-556R
549	10721 DIXON - 3	STILLMAN VALLEY	138	138	WP	0.16			1113 ACSR
550	10721 DIXON - 4	STILLMAN VALLEY	138	138	WH	17.64			1113 ACSR, 2-1277
551	11102 ELECTRIC JUNCTION - 1	WOLFS	138	138	ST	0.54	5.51	1	1113 ACSR, 1033.5
552	11102 ELECTRIC JUNCTION - 2	WOLFS	138	138	SP	0.24			1113 ACSR
553	11103 ELECTRIC JUNCTION - 1	AURORA E.C.	138	138	SP	0.11		1	1113 ACSR
554	11103 ELECTRIC JUNCTION - 2	AURORA E.C.	138	138	ST	1.15			1113 ACSR
555	11105 ELECTRIC JUNCTION - 1	AURORA E.C.	138	138	ST	0.32	0.74	1	1113 ACSR
556	11105 ELECTRIC JUNCTION - 2	AURORA E.C.	138	138	SP	0.05	0.07		1113 ACSR
557	11106 ELECTRIC JUNCTION - 1	WATERMAN	138	138	ST	0.30	9.35	1	1113 ACSR
558	11106 ELECTRIC JUNCTION - 2	WATERMAN	138	138	SP	19.31	0.48		2-556.5 ACSR
559	11106 TAP	CREGO ROAD	138	138	SP	3.97			2-556.5 ACSR,1113
560	11107 ELECTRIC JUNCTION - 1	NAPERVILLE	138	138	SP	0.20	1.27	1	1113 ACSR
561	11107 ELECTRIC JUNCTION - 2	NAPERVILLE	138	138	WP	1.40			1113 ACSR
562	11107 ELECTRIC JUNCTION - 3	NAPERVILLE	138	138	SP	0.07			2-556.5,1113 ACSR
563	11110 ELECTRIC JUNCTION - 1	WOLFS	138	138	ST	2.74	3.22	1	2-556.5,1113 ACSR
564	11110 ELECTRIC JUNCTION - 2	WOLFS	138	138	WP	0.25			2156 ACSR
565	11110 TAP - 1	NAPERVILLE	138	138	SP	0.06	1.27		1113 ACSR
566	11110 TAP - 2	NAPERVILLE	138	138	WH	0.05			1113 ACSR
567	11301WATERMAN - 1	SANDWICH	138	138	SP	0.89	0.48	1	1113 ACSR
568	11301WATERMAN - 2	SANDWICH	138	138	WP	14.16			2-556.5,1113 ACSR
569	11301 TAP	ROW BREAKER AT	138	138	SP	0.01			1113 ACSR
570	11323 WATERMAN	HAUMESSER ROAD	138	138	SP	5.46		1	664.8 ACSS/TW, 11
571	11323 TAP	CREGO ROAD	138	138	SP	5.41			2-556.4, 2156ACSR
572	11413 NORTHWEST	CLYBOURN-CROSBY	138	138	SP	0.02	0.09	1	1113 ACSR
573	11416 NORTHWEST - 1	SKOKIE 88	138	138	ST	1.68	1.89	1	750 CU / 1113 ACS
574	11416 NORTHWEST - 2	SKOKIE 88	138	138	WP	0.06			1113 ACSR
575	11418 NORTHWEST	CROSBY	138	138	SP	0.05	0.09	1	266.8 ACSR
576	11603 GOODINGS GROVE - 1	CRESTWOOD	138	138	ST	11.32		1	1113 ACSR
577	11603 GOODINGS GROVE - 2	CRESTWOOD	138	138	SP	0.05			1113 ACSR
578	11603 GOODINGS GROVE - 3	CRESTWOOD	138	138	WP	0.16			1113 ACSR
579	11605 GOODINGS GROVE	BEDFORD PARK	138	138	ST	18.45		1	900,1113 ACSR
580	11606 GOODINGS GROVE	BEDFORD PARK	138	138	ST	0.71	17.77	1	900 ACSR
581	11609 GOODINGS GROVE - 1	CRESTWOOD	138	138	ST	0.66	10.53	1	1113 ACSR
582	11609 GOODINGS GROVE - 2	CRESTWOOD	138	138	SP	0.24			1113 ACSR
583	11609 GOODINGS GROVE - 3	CRESTWOOD	138	138	WP	0.04			1113 ACSR
584	11701 PROSPECT HTS - 1	DES PLAINES 46	138	138	SP	0.30	3.90	1	1113 ACSR
585	11701 PROSPECT HTS - 2	DES PLAINES 46	138	138	ST	0.23	0.35		1113 ACSR
586	11701 PROSPECT HTS - 3	DES PLAINES 46	138	138	WH	0.11			1113 ACSR
587	11702 PROSPECT HTS - 1	DES PLAINES 46	138	138	SP	0.25	0.35	1	1113 ACSR
588	11702 PROSPECT HTS - 2	DES PLAINES 46	138	138	ST	0.63	3.66		1113 ACSR
589	11702 PROSPECT HTS - 3	DES PLAINES 46	138	138	WH	0.09			1113 ACSR
590	11704 PROSPECT HEIGHTS - 1	APTAKISIC	138	138	ST	0.13	5.41	1	1113 ACSR
591	11704 PROSPECT HEIGHTS - 2	APTAKISIC	138	138	SP	0.22			1113 ACSR
592	11708 PROSPECT HEIGHTS - 1	APTAKISIC	138	138	ST	0.30	5.46	1	1113 ACSR
593	11708 PROSPECT HEIGHTS - 2	APTAKISIC	138	138	SP	0.10	0.03		266.8, 636, 1113A
594	11902 LANCASTER - 1	MARYLAND	138	138	SP	15.89	4.13	1	1113 ACSR
595	11902 LANCASTER - 2	MARYLAND	138	138	ST	1.25	0.69		1113 ACSR
596	11902 LANCASTER - 3	MARYLAND	138	138	WP	0.10	1.01		1113 ACSR,
597	11904 LANCASTER - 1	ECOGROVE WIND FARM	138	138	SP	0.47		1	636, 1113 ACSR
598	11904 LANCASTER - 2	ECOGROVE WIND FARM	138	138	WP	9.46			636, 1113 ACSR
599	11904 LANCASTER - 3	ECOGROVE WIND FARM	138	138	ST	2.24			636 ACSR
600	11904 TAP	FREEPORT	138	138	ST	1.13			266.8, 636, 1113A
601	12007 LOMBARD - 1	ELMHURST	138	138	ST	8.14		1	1113 ACSR
602	12007 LOMBARD - 2	ELMHURST	138	138	WP	0.06			1113 ACSR
603	12008 LOMBARD - 1	ELMHURST	138	138	ST	0.10	8.16	1	900,1113 ACSR
604	12008 LOMBARD - 2	ELMHURST	138	138	SP	0.11			1113 ACSR
605	12015 LOMBARD - 1	ITASCA	138	138	ST	8.12		1	1113 ACSR
606	12015 LOMBARD - 2	ITASCA	138	138	SP	0.09			1113 ACSR
607	12016 LOMBARD - 1	ITASCA	138	138	ST	0.58	7.45	1	1113 ACSR
608	12016 LOMBARD - 2	ITASCA	138	138	SP	0.10			1113 ACSR
609	12016 LOMBARD - 3	ITASCA	138	138	WH	0.29			1113 ACSR
610	12204 BELVEDERE - 1	PLEASANT VALLEY	138	138	ST	22.72		1	1113 ACSR, 664.8A
611	12204 BELVEDERE - 2	PLEASANT VALLEY	138	138	SP	0.63			664.8ACSS/TW
612	12204 TAP	MARENGO	138	138	WP	1.17			477, 1113 ACSR, 6
613	12205 BELVIDERE - 1	WOODSTOCK	138	138	ST	0.21	21.26	1	1113
614	12205 BELVIDERE - 2	WOODSTOCK	138	138	SP	2.71			2-556.5 ACSR,1113
615	12205 TAP	MARENGO	138	138	WH	1.22			477 ACSR
616	12411 MARYLAND - 1	DIXON	138	138	ST	1.45		1	3/0 CO
617	12411 MARYLAND - 2	DIXON	138	138	SP	11.32			1113 ACSR
618	12411 MARYLAND - 3	DIXON	138	138	WH	2.73			3/0 CO
619	12411 TAP	STERLING	138	138	SP	14.38			1113 ACS
620	13219 GARDEN PLAIN	I.S.P.C.O.	138	138	WP	4.52		1	477 ACSR
621	13304 ROCK FALLS	SCHAUFF ROAD	138	138	SP	11.09			2-556.5, 2156ACSR
622	13501 ELMHURST - 1	BELLWOOD	138	138	ST	0.19	5.31	1	900,1113 ACSR
623	13501 ELMHURST - 2	BELLWOOD	138	138	SP	0.07			900,1113 ACSR
624	13501 ELMHURST - 3	BELLWOOD	138	138	WP	0.07			900,1113 ACSR
625	13502 ELMHURST - 1	BELLWOOD	138	138	ST	0.15	5.29	1	900,1113 ACSR
626	13502 ELMHURST - 2	BELLWOOD	138	138	SP	0.11			900,1113 ACSR
627	13502 ELMHURST - 3	BELLWOOD	138	138	WP	0.05			900,1113 ACSR
628	13503 ELMHURST - 1	NORTHLAKE	138	138	ST	0.30	0.42	1	900,1113 ACSR
629	13503 ELMHURST - 2	NORTHLAKE	138	138	WP	0.16			900 ACSR
630	13504 ELMHURST - 1	FRANKLIN PARK	138	138	ST	0.13	0.40	1	1113 ACSR
631	13504 ELMHURST - 2	FRANKLIN PARK	138	138	SP	1.77	0.14		1113 ACSR
632	13504 ELMHURST - 3	FRANKLIN PARK	138	138	WP	0.12			1113 ACSR
633	13510 ELMHURST - 1	FRANKLIN PARK	138	138	ST	0.10	0.46	1	900,1113 ACSR
634	13510 ELMHURST - 2	FRANKLIN PARK	138	138	SP	0.03	1.77		1113 ACSR
635	13510 ELMHURST - 3	FRANKLIN PARK	138	138	WP	0.22			1113 ACSR
636	13803 STATE LINE	NIPSCO	138	138	ST	0.19		1	900,1113 ACSR
637	13805 SILVER LAKE - 1	SW TIE L-18513	138	138	ST	0.23	4.00	1	1113,2156 ACSR
638	13805 SILVER LAKE - 2	SW TIE L-18513	138	138	SP	0.32	7.06		1277.2 ACSR
639	13805 SILVER LAKE - 3	SW TIE L-18513	138	138	WP	0.11			1113 ACSR
640	13805 SILVER LAKE - 4	SW TIE L-18513	138	138	WH	0.22			1113 ACSR
641	13806 SILVER LAKE - 1	SW TIE L-18512	138	138	ST	0.21	3.91	1	1277.2 ACAR, 477,
642	13806 SILVER LAKE - 2	SW TIE L-18512	138	138	SP	0.36	7.05		1277.2 ACAR
643	13806 SILVER LAKE - 3	SW TIE L-18513	138	138	WP	0.18			477,1113 ACSR
644	13806 SILVER LAKE - 4	SW TIE L-18513	138	138	WH		0.22		477,1113 ACSR
645	13808 SILVER LAKE - 1	CRYSTAL LAKE	138	138	ST	0.09	2.58	1	1113 ACSR
646	13808 SILVER LAKE - 2	CRYSTAL LAKE	138	138	WP	0.07			1113 ACSR
647	13809 SILVER LAKE - 1	PLEASANT VALLEY	138	138	ST	2.39	7.33	1	477,1113 ACSR
648	13809 SILVER LAKE - 2	PLEASANT VALLEY	138	138	SP	0.14			1113 ACSR
649	14101 PLEASANT VALLEY - 1	CRYSTAL LAKE	138	138	ST	0.01	6.77	1	477,1113 ACSR
650	14101 PLEASANT VALLEY - 2	CRYSTAL LAKE	138	138	SP	0.05	0.12		477,1113 ACSR
651	14101 PLEASANT VALLEY - 3	CRYSTAL LAKE	138	138	WP	0.09			477,1113 ACSR
652	14101 PLEASANT VALLEY - 4	CRYSTAL LAKE	138	138	WH	0.08			477,1113 ACSR
653	14102 PLEASANT VALLEY	TOLLWAY	138	138	SP	26.47	0.96	1	1113 ACSR, 2-556R
654	14103 PLEASANT VALLEY	TOLLWAY	138	138	SP	0.26	27.20	1	1113 ACSR, 2-556R
655	14106 PLEASANT VALLEY - 1	WOODSTOCK	138	138	WP	3.06		1	664.8 ACSS/TW
656	14106 PLEASANT VALLEY - 2	WOODSTOCK	138	138	ST	0.16	0.51		1113 ACSR, 664.8
657	14302 WOLFS - 1	PLANO	138	138	SP		0.14	1	1113 ACSR
658	14302 WOLFS - 2	PLANO	138	138	WP		6.35		477,1113
659	14302 WOLFS - 3	PLANO	138	138	SP	7.00			1113,2156 ACSR
660	14302 TAP	ROW BREAKER AT	138	138	SP	0.02			1113 ACSR
661	14304 WOLFS - 1	PLANO	138	138	SP	0.14		1	1113ACSR
662	14304 WOLFS - 2	PLANO	138	138	WP	6.35			477,1113
663	14304 WOLFS - 3	PLANO	138	138	SP	0.21	6.79		1113, 2156 ACSR
664	14403 WAYNE - 1	AURORA E.C.	138	138	ST	0.01	12.04	1	1113 ACSR
665	14403 WAYNE - 2	AURORA E.C.	138	138	SP	0.30	0.16		1113 ACSR
666	14405 WAYNE - 1	AURORA E.C.	138	138	ST	0.21	11.76	1	1113 ACSR
667	14405 WAYNE - 2	AURORA E.C.	138	138	SP	0.41	0.17		1113 ACSR
668	14609 SANDWICH - 1	PLANO	138	138	SP	0.12		1	1113 ACSR
669	14609 SANDWICH - 2	PLANO	138	138	WP	9.58			1113 ACSR
670	15001 CALUMET	RIVER E.C.	138	138	SP	0.30	1.86	1	636,1113 ACSR
671	15002 CALUMET	RIVER E.C.	138	138	SP	0.34	1.87	1	477,1113 ACSR
672	15410 LIBERTYVILLE - 1	APTAKISIC	138	138	ST	0.25	9.17	1	1113 ACSR
673	15410 LIBERTYVILLE - 2	APTAKISIC	138	138	SP	0.41			1113 ACSR
674	15417 LIBERTYVILLE - 1	APTAKISIC	138	138	ST	0.54	9.10	1	1113 ACSR
675	15417 LIBERTYVILLE - 2	APTAKISIC	138	138	SP	0.17	0.04		1113 ACSR
676	15507 NELSON - 1	DIXON 107	138	138	ST	0.48	9.11	1	477,1113 ACSR
677	15507 NELSON - 2	DIXON 107	138	138	SP		0.78		477,1113 ACSR
678	15508 NELSON - 1	DIXON 107	138	138	ST	9.12	0.47	1	477,1113 ACSR
679	15508 NELSON - 2	DIXON 107	138	138	SP		0.78		477,1113 ACSR
680	15509 NELSON	ROCK FALLS	138	138	ST	2.87		1	1113 ACSR
681	15511 NELSON - 1	DIXON R/W	138	138	ST	0.71		1	1113 ACSR
682	15511 NELSON - 2	DIXON R/W	138	138	SP	4.97			1113 ACSR
683	15511 TAP	STERLING	138	138	SP	0.05			312.8 AAAC / 1113
684	15518 NELSON - 1	GARDEN PLAIN	138	138	ST	0.22	2.62	1	266.8,477,1113 AC
685	15518 NELSON - 2	GARDEN PLAIN	138	138	WP	16.72			1113 AA / 477 ACS
686	15518 NELSON - 3	GARDEN PLAIN	138	138	WH	7.88			266.8 ACSR
687	15518 NELSON - 4	GARDEN PLAIN	138	138	SP	1.49			477 ACSR
688	15518 TAP	ROCK FALLS	138	138	WP	0.04			1113 ACSR
689	15621 CHERRY VALLEY - 1	DIXON	138	138	ST	1.15		1	1113 ACSR
690	15621 CHERRY VALLEY - 2	DIXON	138	138	SP	0.03			1113 ACSR
691	15621 CHERRY VALLEY - 3	DIXON	138	138	WH	16.81			1113 ACSR
692	15622 CHERRY VALLEY - 1	SABROOKE	138	138	ST	0.07	0.36	1	1113 ACSR
693	15622 CHERRY VALLEY - 2	SABROOKE	138	138	SP		7.16		1113 ACSR
694	15623 CHERRY VALLEY - 1	BELVIDERE	138	138	ST	3.85	4.74	1	1277.2 ACAR / 215
695	15623 CHERRY VALLEY - 2	BELVIDERE	138	138	WP	0.16			1277.2 ACAR / 215
696	15624 CHERRY VALLEY - 1	BELVIDERE	138	138	ST	0.34	1.17	1	1113 ACSR
697	15624 CHERRY VALLEY - 2	BELVIDERE	138	138	WP	6.53			1113 ACSR
698	15624 CHERRY VALLEY - 3	BELVIDERE	138	138	WH	0.10			1113 ACSR
699	15625 CHERRY VALLEY - 1	WEMPLETOWN	138	138	ST	0.44	22.39	1	1113,2156 ACSR
700	15625 CHERRY VALLEY - 2	WEMPLETOWN	138	138	SP	0.10	2.60		1113,2-556.5 ASCR
701	15625 CHERRY VALLEY - 3	WEMPLETOWN	138	138	WP	0.06			1113 ACSR
702	15626 CHERRY VALLEY - 1	SABROOKE	138	138	ST	0.10	0.36	1	1113 ACSR
703	15626 CHERRY VALLEY - 2	SABROOKE	138	138	SP		7.15		1113 ACSR
704	15627 CHERRY VALLEY - 1	GLIDDEN	138	138	ST	21.00	0.98	1	1113,2156 ACSR
705	15627 CHERRY VALLEY - 2	GLIDDEN	138	138	WP	7.15			1113 ACSR
706	15912 NORTHBROOK 159 - 1	HIGHLAND PARK	138	138	ST		4.02	1	1113 ACSR
707	15912 NORTHBROOK 159 - 2	HIGHLAND PARK	138	138	SP	0.35	0.35		1113 ACSR,2156 ACSR
708	15913 NORTHBROOK 159 - 1	HIGHLAND PARK	138	138	ST	4.12		1	1113 ACSR
709	15913 NORTHBROOK 159 - 2	HIGHLAND PARK	138	138	SP	0.73			1113,2156 ACSR
710	16901 MCGIRR ROAD - 1	SHADY OAKS	138	138	WP	11.29		1	1113 ACSR
711	16901 MCGIRR ROAD - 2	SHADY OAKS	138	138	SP	0.09			1113 ACSR
712	16901 TAP	MENDOTA HILLS	138	138	SP	0.04			1113 ACSR
713	16914 MCGIRR ROAD - 1	STEWARD	138	138	SP	0.22	0.01	1	1113 ACSR
714	16914 MCGIRR ROAD - 2	STEWARD	138	138	SH	1.21			1113 ACSR
715	16914 TAP - 1	RITCHIE ROAD	138	138	WP	1.08			266.8 ACSR
716	16914 TAP - 2	RITCHIE ROAD	138	138	SP	4.19			556.5, 1113 ACSR, T2-556.5 ACSR
717	17008 HARBOR	UNIVERSITY	138	138	SP	0.50	5.45	1	1113,2156 ACSR
718	17113 SABROOKE - 1	WEMPLETOWN	138	138	ST	3.69	0.34	1	1113 ACSR
719	17113 SABROOKE - 2	WEMPLETOWN	138	138	SP	2.95	3.71		1113 ACSR
720	17113 SABROOKE - 3	WEMPLETOWN	138	138	WP	0.33			1113 ACSR
721	17113 SABROOKE - 4	WEMPLETOWN	138	138	WH	0.20		1	1113 ACSR
722	17121 WEMPLETOWN - 1	LANCASTER	138	138	WP	1.03		1	1113 ACSR
723	17121 WEMPLETOWN - 2	LANCASTER	138	138	SP	22.17			477,1113 ACSR
724	17712 BURNHAM - 1	CHICAGO HTS	138	138	SP	0.56		1	1113 ACSR
725	17712 BURNHAM - 2	CHICAGO HTS	138	138	ST		9.42		1113 ACSR
726	17713 BURNHAM - 1	WILDWOOD	138	138	ST	5.05		1	900,1113 ACSR
727	17713 BURNHAM - 2	WILDWOOD	138	138	SP	0.40			1113 ACSR
728	17714 BURNHAM - 1	WILDWOOD	138	138	ST		5.13	1	900,1113 ACSR
729	17714 BURNHAM - 2	WILDWOOD	138	138	SP	0.13	0.13		1113 ACSR
730	17714 TAP	HEGEWISCH	138	138	ST	0.33	1.89		1113 ACSR
731	17715 BURNHAM - 1	TOWER AUTOMOTIVE	138	138	ST		2.27	1	1113 ACSR
732	17715 BURNHAM - 2	TOWER AUTOMOTIVE	138	138	SP	0.36	0.08		1113 ACSR
733	17903 BLOOM	MATTESON	138	138	ST		6.07	1	1113 ACSR
734	17904 BLOOM	MATTESON	138	138	ST	0.25	5.82	1	1113 ACSR
735	18512 TOLLWAY	SW TIE L-13806	138	138	SP	2.80		1	1277.2 ACAR /111
736	18512 TAP	ROCKY ROAD E.C.	138	138	WP	0.01			1277.2 ACAR
737	18513 TOLLWAY	SW TIE L-13805	138	138	SP	0.58	2.24	1	1277.2 ACAR / 111
738	18513 TAP	ROCKY ROAD E.C.	138	138	WP	0.03			1113 ACSR
739	18706 SCHAUFF ROAD - 1	KEEMIN (AMEREN)	138	138	SP	0.07		1
740	18706 SCHAUFF ROAD - 2	KEEMIN (AMEREN)	138	138	ST	24.88			477 ACSR
741	18618 STEWARD - 1	TWOMBLY ROAD	138	138	WP	11.26		1	556.5 ACSR
742	18618 STEWARD - 2	TWOMBLY ROAD	138	138	SP	0.10			556.5 ACSR
743	18623 STEWARD	HAUMESSER ROAD	138	138	SP	7.21		1	1113 ACSR, 664.8A
744	19414 SABROOKE - 1	LANCASTER	138	138	ST	2.35		1	636,1113 ACSR
745	19414 SABROOKE - 2	LANCASTER	138	138	SP	6.95			1113 ACSR
746	19414 SABROOKE - 3	LANCASTER	138	138	WP	21.14			1113 ACSR
747	28201 ZION TDC 282 - 1	IL-WI STATE LINE	138	138	ST	0.10	1.79	1	1113 ACSR
748	28201 ZION TDC 282 - 2	IL-WI STATE LINE	138	138	SP	0.25	0.14		1113 ACSR
749	28201 ZION TDC 282 - 3	IL-WI STATE LINE	138	138	WH	1.79			477 ACSR
750	52517 NORMANTOWN	BOLINGBROOK	138	138	SP	0.16	2.81	1
751	138KV LINES								138kV LINES
752	0702 ILL-IND STATE LINE	WASHINGTON PARK	138	138	UG	8.44		1	800 MM2 XLPE
753	0705 ILL-IND STATE LINE	WASHINGTON PARK	138	138	UG	9.75			800 MM2 XLPE
754	1106 QUARY	STATE	138	138	UG	2.27			1200 MM2 XLPE / 2
755	1106 FISK	TERMINAL	138	138	UG	0.15			1600 kcmil XLPE
756	1108 QUARY	STATE	138	138	UG	2.26			1200 MM2 XLPE
757	1110 FISK	DEKOVEN	138	138	UG	2.16		1	1600 MM2 XLPE
758	1111 FISK	DEKOVEN	138	138	UG	2.28		1	1600 MM2 XLPE
759	1306 RIDGELAND	LEXTENSION PT	138	138	UG	0.31			1600 MM2 XLPE
760	1317 CRAWFORD	FISK	138	138	UG	4.46		1	2500 HPFF
761	1318 CRAWFORD	FISK	138	138	UG	4.49		1	2500 HPFF
762	1320 CRAWFORD	JEFFERSON	138	138	UG	6.93		1	800 MM2 XLPE
763	1322 CRAWFORD	HAYFORD	138	138	UG	0.34			1600 MM2 XLPE
764	1324 CRAWFORD	HAYFORD	138	138	UG	0.33			1600 MM2 XLPE
765	1326 CRAWFORD	JEFFERSON	138	138	UG	6.72		1	800 MM2 XLPE
766	3610 DEKOVEN	MADISON	138	138	UG	1.07		1	1600 MM2 XLPE
767	3611 DEKOVEN	MADISON	138	138	UG	1.07		1	1600 MM2 XLPE
768	3701Y NATOMA	GALEWOOD	138	138	UG	0.37		1	250 kcmil HPFF
769	3702Y NATOMA	GALEWOOD	138	138	UG	0.43		1	350 kcmil HPFF
770	3703Y NATOMA	GALEWOOD	138	138	UG	0.37		1	250 kcmil HPFF
771	3704Y NATOMA	GALEWOOD	138	138	UG	0.37		1	250 kcmil HPFF
772	3710 FRANKLIN PARK	NATOMA	138	138	UG	5.46		1	2000 kcmil HPFF
773	3705 NATOMA	FRANKLIN PARK	138	138	UG	6.09		1	2000 kcmil HPFF
774	3706 NATOMA	HIGGINS	138	138	UG	4.56		1	2000 kcmil HPFF
775	3707 NATOMA	NORRIDGE	138	138	UG	4.56		1	2000 kcmil HPFF
776	3709 NATOMA	OAK PARK	138	138	UG	3.14		1	2000 kcmil HPFF
777	4522 FISK	JEFFERSON	138	138	UG	2.14		1	2500 kcmil HPFF
778	4523 FISK	JEFFERSON	138	138	UG	2.13		1	2500 kcmil HPFF
779	4525 JEFFERSON	GRAND	138	138	UG	1.94		1	1600 MM2 XLPE
780	4527 JEFFERSON	GRAND	138	138	UG	1.87		1	1600 MM2 XLPE
781	4018 DIVERSEY	CROSBY	138	138	UG	2.59		1	2500 kcmil HPFF
782	4607 DESPLAINES	HIGGINS	138	138	UG	7.57		1	2000 kcmil HPFF
783	5105X RIDGELAND	TERMINAL C	138	138	UG	0.24			1600 MM2 XLPE
784	5105Y RIDGELAND	TERMINAL C	138	138	UG	0.17			1600 MM2 XLPE
785	5107X MCCOOK	TERMINAL O	138	138	UG	0.08			1600 MM2 XLPE
786	5107Y MCCOOK	TERMINAL Q	138	138	UG	0.08			1600 MM2 XLPE
787	5810 MADISON	GRAND	138	138	UG	1.17		1	1600 MM2 XLPE
788	5811 MADISON	GRAND	138	138	UG	1.17		1	1600 MM2 XLPE
789	5825 GRAND	CROSBY	138	138	UG	1.05		1	1600 MM2 XLPE
790	5826 GRAND	WEST LOOP	138	138	UG	1.50		1	1600 MM2 XLPE
791	5827 GRAND	CROSBY	138	138	UG	0.94		1	1600 MM2 XLPE
792	5828 GRAND	WEST LOOP	138	138	UG	1.40		1	1600 MM2 XLPE
793	8221 CROSBY	ROCKWELL	138	138	UG	1.95			1600 MM2 XLPE
794	8223 CROSBY	ROCKWELL	138	138	UG	1.95			1600 MM2 XLPE
795	11411 NORTHWEST	DEVON	138	138	UG	5.62		1	2000 kcmil HPFF
796	11412 NORTHWEST	NATOMA	138	138	UG	6.45		1	2000 kcmil HPFF
797	11413 NORTHWEST	DIVERSEY	138	138	UG	1.86			2000 kcmil HPFF,2
798	11416 NORTHWEST	DEVON	138	138	UG	5.85			800 MM2 XLPE
799	11417 NORTHWEST	NATOMA	138	138	UG	6.08		1	2000 kcmil HPFF
800	11418 ADDISON RIVER	DIVERSEY	138	138	UG	1.70			2000 kcmil HPFF
801	13503 NORTHLAKE	FRANKLIN PARK	138	138	UG	1.54			2000 kcmil HPFF
802	13701 WASHINGTON PARK	JEFFERSON	138	138	UG	8.25		1	800 MM2 XLPE
803	13701 JEFFERSON	GRENSHAW	138	138	UG	0.52			2500 kcmil HPFF
804	14807 WEST LOOP	CLYBOURN	138	138	UG	1.55		1	1600 mm2 XLPE
805	14818 WEST LOOP	DIVERSEY	138	138	UG	3.24		1	1600 MM2 XLPE
806	14826 WEST LOOP	CROSBY	138	138	UG	0.55		1	1600 MM2 XLPE
807	14828 WEST LOOP	CROSBY	138	138	UG	0.65		1	1600 MM2 XLPE
808	15301 TAYLOR	GRENSHAW	138	138	UG	0.20		1	1600 MM2 XLPE
809	15302 TAYLOR	JEFFERSON	138	138	UG	0.91		1	2000 kcmil HPFF
810	15303 TAYLOR	JEFFERSON	138	138	UG	0.50		1	2500 kcmil HPFF
811	15310 TAYLOR	GRENSHAW	138	138	UG	0.19		1	1600 MM2 XLPE
812	15315 LASALLE	STATE	138	138	UG	0.91		1	1200 MM2 XPLE
813	15315 TAYLOR	LASALLE	138	138	UG	0.82			2500 kcmil HPFF
814	15316 TAYLOR	LASALLE	138	138	UG	0.77		1	2500 kcmil HPFF
815	15317 TAYLOR	LASALLE	138	138	UG	0.76		1	2500 kcmil HPFF
816	15317 LASALLE	STATE	138	138	UG	0.91			1200 MM2 XPLE
817	15318 TAYLOR	LASALLE	138	138	UG	0.78		1	2500 kcmil HPFF
818	17008 61ST STREET	UNIVERSITY	138	138	UG	2.45			2000 kcmil HPFF
819	17401 UNIVERSITY	GRENSHAW	138	138	UG	6.49		1	2000 kcmil HPFF
820	17404 UNIVERSITY	WASHINGTON PARK	138	138	UG	2.20		1	2000 kcmil HPFF
821	19209 RIDGELAND	OAK PARK	138	138	UG	5.35		1	2000 kcmil HPFF
822	19801 DESPLAINES	NORRIDGE	138	138	UG	4.67		1	2000 kcmil HPFF
823	7405 KEWANEE - 1	SCHAUFF ROAD	138	138	SP	0.06		1	1590ACSR
824	7405 KEWANEE - 2	SCHAUFF ROAD	138	138	ST		31.70		477ACSR
825	18702 SCHAUFF ROAD	ROCK FALLS	138	138	SP	0.12	11.01	1	2-556.5, 1590ACSR
826	8302 GLIDDEN	CREGO ROAD	138	138	SP	3.63		1	2-556.5 ACSR, 2156 ACSR
827	8309 GLIDDEN	CREGO ROAD	138	138	SP	5.09		1	2-556.5, 2156 ACSR
828	15515 NELSON	SCHAUFF ROAD	138	138	SP	17.55		1	2-556.5, 1590 ACSR
829	18407 ELK GROVE - 1	TONNE	138	138	SP	0.16		1	1113 ACSR
830	18407 ELK GROVE - 2	TONNE	138	138	T	0.09	2.39		1113 ACSR
831	18408 ELK GROVE - 1	TONNE	138	138	SP	0.24		1	1113 ACSR
832	18408 ELK GROVE - 2	TONNE	138	138	T		2.39		1113 ACSR
833	1 RITCHIE ROAD	CARON ROAD	138	138	SP	1.45		1	556.5, T2-556.5 ACSR
834	59306 WILLOW SPRINGS - 1	BURR RIDGE	138	138	ST	0.07	5.14	1	1113 ACSR
835	59306 WILLOW SPRINGS - 2	BURR RIDGE	138	138	SP	0.12	0.11		1113 ACSR
836	59306 WILLOW SPRINGS - 3	BURR RIDGE	138	138	WP	0.05			1113 ACSR
837	8604 DAVIS CREEK - 1	BRADLEY	138	138	SP	5.48	0.94	1	1113, T2-556.5, ACSR
838	8604 DAVIS CREEK - 2	BRADLEY	138	138	ST	0.00	0.28		1113 ACSR
839	8604 DAVIS CREEK - 3	BRADLEY	138	138	WP	0.08			1113 ACSR
840	7404 KEWANEE - 1	PUTNAM (AMEREN)	138	138	ST	31.90		1	477 ACSR
841	7404 KEWANEE - 2	PUTNAM (AMEREN)	138	138	SP	0.14	0.29		2-556.5 ACSR
842	98105 CRESCENT RIDGE - 1	CORBIN (AMEREN)	138	138	SP	0.28	0.48	1	477,1113,2-556.5 ACSR
843	98105 CRESCENT RIDGE - 2	CORBIN (AMEREN)	138	138	ST		27.48		477 ACSR
844	19906 KENSINGTON	CSL BEHRING	138	138	SP	4.77		1	1113 ACSR
845	19907 KENSINGTON	CSL BEHRING	138	138	SP	0.13	4.64	1	1113 ACSR
36	TOTAL					3,055	1,954	391		131,588,062	2,813,264,683	2,944,852,745

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: TransmissionLineStartPoint


The statistical data on pages 422 through 423 excludes High Voltage Distribution lines consistent with the Plant in Service balance reported on pages 422 and 423, columns (j), (k) and (l), rows 1, 2, and 3.

(b) Concept: TransmissionLineStartPoint


10808 from Lockport to Lombard was merged with 12001 from Lombard to Itasca in 2024. The result is one line, 10808 from Lockport to Itasca, that contains all the mileage of the two former lines. 12001 has been removed.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

TRANSMISSION LINES ADDED DURING YEAR

Report below the information called for concerning Transmission lines added or altered during the year. It is not necessary to report minor revisions of lines.
Provide separate subheadings for overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (l) to (o), it is permissible to report in these columns the costs. Designate, however, if estimated amounts are reported. Include costs of Clearing Land and Rights-of-Way, and Roads and Trails, in column (l) with appropriate footnote, and costs of Underground Conduit in column (m).
If design voltage differs from operating voltage, indicate such fact by footnote; also where line is other than 60 cycle, 3 phase, indicate such other characteristic.

LINE DESIGNATION

SUPPORTING STRUCTURE

CIRCUITS PER STRUCTURE

CONDUCTORS

LINE COST

Line No.

(a)

(b)

(c)

(d)

(e)

(f)

(g)

(h)

(i)

(j)

(k)

(l)

(m)

(n)

(o)

(p)

(q)

138 kV Overhead

Line Sections Installed

Total - 1

345 kV Overhead

Total - 2

TOTAL

0.00

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2024

Year/Period of Report

End of:

2024

SUBSTATIONS
Report below the information called for concerning substations of the respondent as of the end of the year. Substations which serve only one industrial or street railway customer should not be listed below. Substations with capacities of Less than 10 MVA except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (f). Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company.
		Character of Substation		VOLTAGE (In MVa)						Conversion Apparatus and Special Equipment
Line No.	SubstationNameAndLocation Name and Location of Substation (a)	SubstationCharacterDescription Transmission or Distribution (b)	SubstationCharacterAttendedOrUnattended Attended or Unattended (b-1)	PrimaryVoltageLevel Primary Voltage (In MVa) (c)	SecondaryVoltageLevel Secondary Voltage (In MVa) (d)	TertiaryVoltageLevel Tertiary Voltage (In MVa) (e)	SubstationInServiceCapacity Capacity of Substation (In Service) (In MVa) (f)	NumberOfTransformersInService Number of Transformers In Service (g)	Number of Spare Transformers (h)	ConversionApparatusAndSpecialEquipmentType Type of Equipment (i)	NumberOfConversionApparatusAndSpecialEquipmentUnits Number of Units (j)	CapacityOfConversionApparatusAndSpecialEquipment Total Capacity (In MVa) (k)
1	CHICAGO (OVER 10 MVA)
2	89-BEVERLY	Distribution	Unattended	138.00	12.50		132	4
3	150-CALUMET-1	Distribution	Attended	138.00	12.50		300	4
4	150-CALUMET-2	Distribution	Attended	138.00	69.00		120	3
5	54-CLYBOURN	Distribution	Unattended	138.00	12.50		200	4
6	30-COLUMBUS PARK-1	Distribution	Unattended	69.00	12.50		219	6
7	13-CRAWFORD-1	Transmission	Unattended	345.00	138.00	34.00	1200	4
8	13-CRAWFORD-2	Distribution	Unattended	138.00	12.50		400	8
9	82-CROSBY	Distribution	Unattended	138.00	12.50		200	4
10	814-DAMEN	Distribution	Unattended	138.00	12.50		80	2
11	87-DEARBORN	Distribution	Unattended	69.00	12.50		160	4
12	110-DEVON	Distribution	Unattended	138.00	12.50		160	4
13	40-DIVERSEY	Distribution	Unattended	138.00	12.50		200	4
14	11-FISK-1	Transmission	Unattended	345.00	138.00	34.00	600	2
15	11-FISK-2	Distribution	Unattended	138.00	12.50		200	3
16	104-FORD CITY	Distribution	Unattended	138.00	12.50		100	3
17	31-GALEWOOD-1	Distribution	Unattended	138.00	12.50		160	4
18	90-DEKOVEN	Distribution	Unattended	138.00	69.00		400	2
19	32-HANSON PARK-1	Distribution	Unattended	138.00	12.50		160	4
20	33-HAYFORD	Distribution	Unattended	138.00	12.50		120	4
21	55-HEGEWISCH	Distribution	Unattended	138.00	12.50		146	4
22	71-HIGGINS	Distribution	Unattended	138.00	12.50		160	4
23	38-HUMBOLDT PARK-1	Distribution	Unattended	138.00	12.50		200	4
24	745-I.C.AIR RIGHTS	Distribution	Unattended	138.00	12.50		200	4
25	45-JEFFERSON-1	Distribution	Unattended	138.00	12.50		250	5
26	45-JEFFERSON-2	Distribution	Unattended	138.00	69.00	12.50	800	12
27	34-KINGSBURY	Distribution	Unattended	138.00	12.50		200	4
28	68-LA SALLE	Distribution	Unattended	138.00	12.50		200	4
29	36-MADISON	Distribution	Unattended	138.00	12.50		250	5
30	714-MEDICAL CENTER	Distribution	Unattended	138.00	12.50		200	4
31	37-NATOMA	Distribution	Unattended	138.00	12.50		100	2
32	648-NORRIDGE	Distribution	Unattended	138.00	12.50		160	4
33	114-NORTHWEST-1	Distribution	Unattended	138.00	12.50	12.50	375	5
34	114-NORTHWEST-2	Distribution	Unattended	138.00	12.50		160	4
35	65-OHIO	Distribution	Unattended	138.00	12.50		250	5
36	785-ONTARIO	Distribution	Unattended	138.00	12.50		200	4
37	49-PLYMOUTH COURT	Distribution	Unattended	69.00	12.50		160	4
38	39-PORTAGE	Distribution	Unattended	138.00	12.50		268	8
39	840-QUARRY	Distribution	Unattended	138.00	12.50		200	4
40	84-ROSEHILL	Distribution	Unattended	138.00	12.50		200	4
41	41-ROSELAND	Distribution	Unattended	69.00	12.50		99	3
42	63-SAWYER	Distribution	Unattended	138.00	12.50		132	4
43	784-SEARS	Distribution	Unattended	138.00	12.50		200	4
44	126-STATE	Distribution	Unattended	138.00	12.50		200	4
45	153-TAYLOR	Transmission	Unattended	345.00	138.00	34.00	600	2
46	174-UNIVERSITY	Distribution	Unattended	138.00	12.50		200	4
47	118-WALLACE	Distribution	Unattended	138.00	12.50		106	3
48	137-WASHINGTON PARK	Distribution	Unattended	138.00	12.50		225	3
49	148-WEST LOOP	Transmission	Unattended	345.00	138.00	34.00	600	2
50	43-WILDWOOD-1	Distribution	Unattended	138.00	12.50		66	2
51	X310-ALBANY PARK	Distribution	Unattended	12.50	4.00		22	3
52	Z300-ARCHER	Distribution	Unattended	12.50	4.00		11	3
53	Y310-AUSTIN	Distribution	Unattended	12.50	4.00		18	3
54	X301-BELMONT	Distribution	Unattended	12.50	4.00		22	3
55	679-BESLEY COURT	Distribution	Unattended	12.50	4.00		25	4
56	Y365-CAMPBELL	Distribution	Unattended	12.50	4.00		24	3
57	798-CARROLL	Distribution	Unattended	12.50	4.00		17	3
58	666-CENTER	Distribution	Unattended	12.50	4.00		15	2
59	X304-CHASE	Distribution	Unattended	34.00	4.00		15	2
60	X381-CORTLAND	Distribution	Unattended	12.50	4.00		22	3
61	750-CRAGIN	Distribution	Unattended	12.50	4.00		26	3
62	Z310-DREXEL	Distribution	Unattended	12.50	4.00		15	3
63	X300-EASTWOOD	Distribution	Unattended	12.50	4.00		24	3
64	Z312-EXCHANGE	Distribution	Unattended	12.50	4.00		15	3
65	31-GALEWOOD-2	Distribution	Unattended	12.50	4.00		15	3
66	834-GRAND CROSSING	Distribution	Unattended	12.50	4.00		30	5
67	894-HARPER	Distribution	Unattended	12.50	4.00		20	3
68	38-HUMBOLDT PARK-2	Distribution	Unattended	12.50	4.00		30	4
69	860-HYDE PARK	Distribution	Unattended	12.50	4.00		20	3
70	674-IRVING PARK	Distribution	Unattended	12.50	4.00		15	2
71	Z314-JUSTINE	Distribution	Unattended	12.50	4.00		15	2
72	793-LARAMIE	Distribution	Unattended	12.50	4.00		22	3
73	603-LAWRENCE	Distribution	Unattended	12.50	4.00		15	2
74	821-MARQUETTE PARK	Distribution	Unattended	12.50	4.00		22	3
75	895-MARSHFIELD	Distribution	Unattended	12.50	4.00		15	2
76	X313-MONTROSE	Distribution	Unattended	12.50	4.00		24	3
77	Z306-NARRAGANSETT	Distribution	Unattended	34.00	12.00		16	2
78	X312-NEWPORT	Distribution	Unattended	12.50	4.00		13	2
79	X315-NEVA #1	Distribution	Unattended	12.50	4.00		12	3
80	687-NORWOOD PARK	Distribution	Unattended	12.5	4		25	4
81	741-PERSHING	Distribution	Unattended	12.5	4		22	3
82	884-PRAIRIE	Distribution	Unattended	12.5	4		13	3
83	X307-ROSEMONT	Distribution	Unattended	34.0	4		15	2
84	626-SCHOOL	Distribution	Unattended	13	4		12	2
85	Z335-SOUTH CHICAGO	Distribution	Unattended	12.5	4		30	4
86	875-THROOP	Distribution	Unattended	12.5	4		18	3
87	X319-UPTOWN	Distribution	Unattended	12.5	4		24	3
88	851-WASHTENAW	Distribution	Unattended	12.5	4		23	3
89	691-WAVELAND	Distribution	Unattended	12.5	4		28	4
90	761-WENDELL	Distribution	Unattended	12.5	4		28	3
91	855-WINDSOR PARK	Distribution	Unattended	12.5	4		23	3
92	X380-WRIGHTWOOD	Distribution	Unattended	12.5	4		23	3
93	Y314-17TH STREET	Distribution	Unattended	12.5	4		23	3
94	Y302-27TH STREET	Distribution	Unattended	12.5	4		15	2
95	Y308-28TH STREET	Distribution	Unattended	12.5	4		23	3
96	871-56TH STREET	Distribution	Unattended	12.5	4		15	2
97	853-62ND STREET	Distribution	Unattended	12.5	4		15	2
98	896-111TH STREET	Distribution	Unattended	12.5	4		12	4
99	X318-MERRIMAC	Distribution	Unattended	12.5	4		11	3
100	CHICAGO (UNDER 10 MVA)
101	X315-NEVA #2	Distribution	Unattended	13	4		3	1
102	30-COLUMBUS PARK-2	Distribution	Unattended	12.5	4		6	1
103	Z302-EWING	Distribution	Unattended	12.5	4		8	2
104	32-HANSON PARK-2	Distribution	Unattended	12.5	4		4	1
105	Z305-KEATING	Distribution	Unattended	12.5	4		8	2
106	X311-LEHIGH	Distribution	Unattended	34	4		6	1
107	Z307-NEWCASTLE	Distribution	Unattended	34	12.5		9	1
108	X39-PORTAGE PARK	Distribution	Unattended	12.5	4		3	1
109	X368-SAUGANASH#1	Distribution	Unattended	12.5	4		3	1
110	X368-SAUGANASH#2	Distribution	Unattended	12.5	4		8	2
111	X305-SEMINARY	Distribution	Unattended	12.5	4		7	1
112	43-WILDWOOD-2	Distribution	Unattended	12.5	4		5	1
113	OUTSIDE CHICAGO (OVER 10MVA)
114	240-CARY	Distribution	Unattended	138	12.5		80	2
115	569-SUGAR GROVE-1	Distribution	Unattended	138	12.5		80	2
116	101-ITASCA	Distribution	Unattended	138.00	12.50		120	3
117	259-ALGONQUIN	Distribution	Unattended	138.00	12.50		120	3
118	552-ADDISON	Distribution	Unattended	138.00	12.50		73	2
119	160-ALPINE-1	Distribution	Unattended	138.00	12.50		106	3
120	160-ALPINE-2	Distribution	Unattended	138.00	69.00		50	1
121	60-ALSIP-1	Distribution	Unattended	138.00	12.50		146	4
122	60-ALSIP-2	Distribution	Unattended	138.00	34.00	12.50	80	2
123	230-ANTIOCH	Distribution	Unattended	138.00	12.50		80	2
124	109-APTAKISIC	Distribution	Unattended	138.00	12.50		160	4
125	487-ARCHER	Distribution	Unattended	138.00	12.50		80	2
126	268-ARLINGTON	Distribution	Unattended	138.00	12.50		160	4
127	233-BARRINGTON	Distribution	Unattended	138.00	12.50		80	4
128	250-BARRINGTON HILLS	Distribution	Unattended	138.00	12.50		12	1
129	574-BARTLETT	Distribution	Unattended	138.00	12.50		146	4
130	391-ARGYLE	Distribution	Unattended	138.00	12.50		60	2
131	115-BEDFORD PARK-1	Transmission	Unattended	345.00	138.00	34.00	1200	4
132	115-BEDFORD PARK-2	Distribution	Unattended	138.00	34.00	12.50	180	5
133	64-BELLWOOD-1	Distribution	Unattended	138.00	12.50		106	3
134	64-BELLWOOD-2	Distribution	Unattended	138.00	34.00	12.50	240	4
135	416-BELL ROAD	Distribution	Unattended	138.00	12.50		146	4
136	122-BELVIDERE-1	Distribution	Unattended	138.00	34.00	12.50	120	2
137	122-BELVIDERE-2	Distribution	Unattended	138.00	12.50		80	2
138	549-BERKELEY	Distribution	Unattended	138.00	12.50		80	2
139	556-BERWYN-1	Distribution	Unattended	69.00	12.50		80	2
140	387-BLACKHAWK	Distribution	Unattended	138.00	12.50		40	2
141	179-BLOOM-1	Transmission	Unattended	345.00	138.00	34.00	300	1
142	179-BLOOM-2	Distribution	Unattended	138.00	12.50		73	2
143	76-BLUE ISLAND-1	Transmission	Unattended	345.00	138.00	34.00	1200	4
144	76-BLUE ISLAND-2	Distribution	Unattended	138.00	34.00	12.50	120	3
145	76-BLUE ISLAND-3	Distribution	Unattended	138.00	12.50		100	3
146	561-BOLINGBROOK	Distribution	Unattended	138.00	12.50		160	4
147	70-BRADLEY-1	Distribution	Unattended	138.00	34.00	12.50	160	4
148	70-BRADLEY-2	Distribution	Unattended	138.00	12.50		146	4
149	531-BRIDGEVIEW	Distribution	Unattended	138.00	12.50		80	2
150	474-BRIGGS	Distribution	Unattended	138.00	12.50		80	2
151	J19-BRUCE ROAD	Distribution	Unattended	34.00	12.50		16	2
152	237-BUFFALO GROVE	Distribution	Unattended	138.00	12.50		80	2
153	177-BURNHAM	Transmission	Unattended	345.00	138.00	34.00	600	2
154	136-BURR RIDGE	Distribution	Unattended	138.00	12.50		160	4
155	152-BUSSE-1	Distribution	Unattended	138.00	34.00	12.50	120	2
156	152-BUSSE-2	Distribution	Unattended	138.00	12.50		160	4
157	557-BUTTERFIELD	Distribution	Unattended	138.00	12.50		80	2
158	433-CHANNAHON WEST-1	Distribution	Unattended	138.00	12.50		20	1
159	380-CHARLES	Distribution	Unattended	138.00	13.20		73	2
160	156-CHERRY VALLEY	Transmission	Unattended	345.00	138.00	34.00	900	3
161	73-CHICAGO HEIGHTS	Distribution	Unattended	138.00	34.00	12.50	180	3
162	568-CHURCH ROAD	Distribution	Unattended	138.00	12.50		80	2
163	59-CICERO-1	Distribution	Unattended	69.00	12.50		78	3
164	550-CLEARING	Distribution	Unattended	138.00	12.50		113	3
165	23-COLLINS	Transmission	Unattended	765.00	345.00	34.00	1000	3
166	435-COUNTRY CLUB HILLS	Distribution	Unattended	138.00	12.50		120	3
167	461-CRESTWOOD	Distribution	Unattended	138.00	12.50		160	4
168	75-CRYSTAL LAKE-1	Distribution	Unattended	138.00	34.00	12.50	120	3
169	75-CRYSTAL LAKE-2	Distribution	Unattended	138.00	12.50		136	4
170	86-DAVIS CREEK-1	Transmission	Unattended	345.00	138.00	34.00	900	3
171	86-DAVIS CREEK-2	Distribution	Unattended	138.00	12.50		40	1
172	213-DEERFIELD	Distribution	Unattended	138.00	12.50		160	4
173	521-BRISTOL TWP	Distribution	Unattended	138.00	12.50		80	2
174	240-CARY-2	Distribution	Unattended	138.00	12.50		80	2
175	46-DESPLAINES-1	Transmission	Unattended	345.00	138.00	34.00	1200	4
176	46-DESPLAINES-2	Distribution	Unattended	138.00	34.00	12.50	120	2
177	46-DESPLAINES-3	Distribution	Unattended	138.00	12.50		120	3
178	198-DESPLAINES	Distribution	Unattended	138.00	12.50		139	4
179	107-DIXON	Distribution	Unattended	138.00	34.00	12.50	120	2
180	317-DIXON	Distribution	Unattended	138.00	12.50		50	2
181	580-DOWNERS GROVE	Distribution	Unattended	138.00	12.50		160	4
182	12-DRESDEN-1	Transmission	Unattended	345.00	138.00	34.00	600	2
183	12-DRESDEN-2	Distribution	Unattended	138.00	34.00	12.50	40	1
184	260-DUNDEE	Distribution	Unattended	138.00	12.50		80	2
185	66-EAST FRANKFORT	Transmission	Unattended	345.00	138.00	34.00	300	1
186	389-EAST ROCKFORD	Distribution	Unattended	138.00	12.50		80	2
187	111-ELECTRIC JUNCTION-1	Transmission	Unattended	345.00	138.00	34.00	1200	4
188	111-ELECTRIC JUNCTION-2	Distribution	Unattended	138.00	12.50		80	2
189	111-ELECTRIC JUNCTION-3	Distribution	Unattended	138.00	34.00	12.50	120	2
190	370-ELEROY	Distribution	Unattended	138.00	12.50		40	2
191	570-ELGIN	Distribution	Unattended	138.00	12.50		160	4
192	135-ELMHURST-1	Transmission	Unattended	345.00	138.00	34.00	900	3
193	135-ELMHURST-2	Distribution	Unattended	138.00	12.50		80	2
194	258-ELMWOOD	Distribution	Unattended	138.00	12.50		80	2
195	47-EVANSTON-1	Distribution	Unattended	138.00	34.00	12.50	80	2
196	47-EVANSTON-2	Distribution	Unattended	138.00	12.50		160	4
197	433-CHANNAHON WEST-2	Distribution	Unattended	138.00	34.00		60	1
198	469-EVERGREEN	Distribution	Unattended	138.00	12.50		120	3
199	385-FIFTEENTH ST SUB	Distribution	Unattended	69.00	12.50		25	1
200	165-FORDHAM-1	Distribution	Unattended	138.00	12.50		50	1
201	165-FORDHAM-2	Distribution	Unattended	69.00	12.50		83	2
202	57-FOREST PARK	Distribution	Unattended	69.00	12.50		75	3
203	140-FRANKFORT	Distribution	Unattended	138.00	12.50		80	2
204	78-FRANKLIN PARK-1	Distribution	Unattended	138.00	34.00	12.50	240	4
205	78-FRANKLIN PARK-2	Distribution	Unattended	138.00	12.50		100	3
206	121-FREEPORT-1	Distribution	Unattended	138.00	34.00	12.50	80	2
207	121-FREEPORT-2	Distribution	Unattended	138.00	12.50		40	2
208	581-FRONTENAC	Distribution	Unattended	138.00	12.50		160	4
209	132-GARDEN PLAIN-1	Distribution	Unattended	138.00	34.00	12.50	80	3
210	572-GILBERTS	Distribution	Unattended	138.00	12.50		120	3
211	562-GLENDALE HTS	Distribution	Unattended	138.00	12.50		160	4
212	555-GLEN ELLYN	Distribution	Unattended	138.00	12.50		80	2
213	452-GLENWOOD	Distribution	Unattended	138.00	12.50		100	4
214	83-GLIDDEN-1	Distribution	Unattended	138.00	12.50		80	2
215	83-GLIDDEN-2	Distribution	Unattended	138.00	34.00	12.50	80	2
216	172-GOLF MILL-1	Transmission	Unattended	345.00	138.00	34.00	600	2
217	172-GOLF MILL-2	Distribution	Unattended	138.00	12.50		160	4
218	116-GOODINGS GROVE	Transmission	Unattended	345.00	138.00	34.00	1200	4
219	72-GOOSE LAKE	Distribution	Unattended	138.00	34.00	12.50	80	2
220	560-GRACE	Distribution	Unattended	138.00	12.50		80	2
221	458-GREEN LAKE	Distribution	Unattended	138.00	12.50		80	2
222	294-GURNEE	Distribution	Unattended	138.00	12.50		120	3
223	563-HANOVER TWP	Distribution	Unattended	138.00	12.50		80	2
224	388-HARLEM	Distribution	Unattended	138.00	12.50		100	2
225	384-HARRISON	Distribution	Unattended	69.00	12.50		80	2
226	443-HARVEY	Distribution	Unattended	138.00	12.50		80	2
227	52-HAWTHORNE	Distribution	Unattended	69.00	12.50		77	3
228	48-HIGHLAND PARK-1	Distribution	Unattended	138.00	34.00	12.50	120	3
229	48-HIGHLAND PARK-2	Distribution	Unattended	138.00	12.50		73	2
230	436-HILLCREST	Distribution	Unattended	138.00	12.50		160	4
231	214-HOFFMAN ESTATES	Distribution	Unattended	138.00	12.50		160	4
232	215-HOWARD	Distribution	Unattended	138.00	12.50		80	2
233	101-ITASCA-1	Transmission	Unattended	345.00	138.00	34.00	600	2
234	101-ITASCA-2	Distribution	Unattended	138.00	34.00		180	3
235	456-JOLIET CENTRAL	Distribution	Unattended	138.00	12.50		40	2
236	157-KANKAKEE	Distribution	Unattended	138.00	12.50		80	2
237	134-LAGRANGE PARK	Distribution	Unattended	138.00	12.50		120	3
238	222-LAKE BLUFF	Distribution	Unattended	138.00	12.50		80	2
239	234-LAKEHURST	Distribution	Unattended	138.00	12.50		147	4
240	225-LANDMEIER	Distribution	Unattended	138.00	12.50		80	2
241	446-LANSING	Distribution	Unattended	138.00	12.50		80	2
242	1-LASALLE	Transmission	Attended	345.00	138.00	34.00	300	1
243	166-LEITHTON-1	Distribution	Unattended	138.00	34.00	12.50	40	1
244	166-LEITHTON-2	Distribution	Unattended	138.00	12.50		160	4
245	180-LENA	Distribution	Unattended	138.00	34.00	12.50	80	2
246	154-LIBERTYVILLE-1	Transmission	Unattended	345.00	138.00	34.00	600	2
247	154-LIBERTYVILLE-2	Distribution	Unattended	138.00	12.50		106	3
248	103-LISLE-1	Transmission	Unattended	345.00	138.00	34.00	1200	4
249	103-LISLE-2	Distribution	Unattended	138.00	34.00	12.50	120	3
250	103-LISLE-3	Distribution	Unattended	138.00	12.50		153	4
251	120-LOMBARD-1	Transmission	Attended	345.00	138.00	34.00	600	2
252	120-LOMBARD-2	Distribution	Attended	138.00	34.00	12.50	120	3
253	120-LOMBARD-3	Distribution	Attended	138.00	12.50		120	3
254	409-SOUTH JOLIET	Distribution	Unattended	138.00	34.00		180	3
255	248-LAKE ZURICH	Distribution	Unattended	138.00	12.50		120	3
256	123-MARENGO	Distribution	Unattended	138.00	34.00	12.50	160	4
257	124-MARYLAND	Distribution	Unattended	138.00	34.00	12.50	80	2
258	127-MATTESON-1	Distribution	Unattended	138.00	34.00	12.50	80	2
259	127-MATTESON-2	Distribution	Unattended	138.00	12.50		120	3
260	77-MAZON	Distribution	Unattended	138.00	34.00	12.50	80	2
261	51-MCCOOK-1	Transmission	Attended	345.00	138.00	34.00	600	2
262	51-MCCOOK-2	Distribution	Attended	138.00	34.00	12.50	180	3
263	51-MCCOOK-3	Distribution	Attended	138.00	12.50		120	3
264	193-MCHENRY-1	Distribution	Unattended	138.00	34.00	12.50	120	2
265	193-MCHENRY-2	Distribution	Unattended	138.00	34.00		106	3
266	139-MENDOTA	Distribution	Unattended	138.00	34.00	12.50	40	1
267	182-MINONK	Distribution	Unattended	138.00	34.00	12.50	40	1
268	451-MOKENA	Distribution	Unattended	138.00	12.50		160	4
269	106-MONTGOMERY-1	Distribution	Unattended	138.00	34.00	12.50	80	2
270	106-MONTGOMERY-2	Distribution	Unattended	138.00	12.50		80	2
271	216-MT PROSPECT	Distribution	Unattended	138.00	12.50		80	2
272	155-NELSON	Transmission	Unattended	345.00	138.00	34.00	900	3
273	406-NEW LENOX	Distribution	Unattended	138.00	12.50		120	3
274	129-NILES-1	Distribution	Unattended	138.00	34.00	12.50	120	2
275	129-NILES-2	Distribution	Unattended	138.00	12.50		120	3
276	565-NORDIC	Distribution	Unattended	138.00	12.50		80	2
277	125-NORMANDY	Distribution	Unattended	138.00	34.00	2.40	60	2
278	525-NORMANTOWN	Distribution	Unattended	138.00	12.50		80	2
279	56-NORTH AURORA-1	Distribution	Unattended	138.00	34.00	12.50	160	4
280	56-NORTH AURORA-2	Distribution	Unattended	138.00	12.50		140	4
281	159-NORTHBROOK	Transmission	Unattended	345.00	138.00	34.00	600	2
282	212-NORTHBROOK	Distribution	Unattended	138.00	12.50		160	4
283	69-NORTH CHICAGO-1	Distribution	Unattended	138.00	34.00	12.50	80	2
284	566-OAKBROOK	Distribution	Unattended	138.00	12.50		160	4
285	505-OAKPARK	Distribution	Unattended	138.00	12.50		120	3
286	204-OLD ELM	Distribution	Unattended	138.00	12.50		120	3
287	470-ORLAND	Distribution	Unattended	138.00	12.50		80	2
288	592-OSWEGO	Distribution	Unattended	138.00	12.50		120	3
289	102-PALATINE-1	Distribution	Unattended	138.00	34.00	12.50	80	2
290	102-PALATINE-2	Distribution	Unattended	138.00	12.50		160	4
291	440-PALOS	Distribution	Unattended	138.00	12.50		80	2
292	457-PARK FOREST	Distribution	Unattended	138.00	12.50		67	2
293	386-PECATONICA	Distribution	Unattended	138.00	12.50		10	1
294	162-PIERPONT-1	Distribution	Unattended	138.00	12.50		60	2
295	162-PIERPONT-2	Distribution	Unattended	69.00	12.50		25	1
296	221-NORTH HUNTLEY	Distribution	Unattended	138.00	12.50		80	2
297	454-PLAINFIELD	Distribution	Unattended	138.00	12.50		120	3
298	444-MINOOKA	Distribution	Unattended	138.00	12.50		80	2
299	167-PLANO-1	Transmission	Unattended	765.00	345.00	34.00	2000	6
300	167-PLANO-2	Transmission	Unattended	345.00	138.00	34.00	300	1
301	527-PLANO	Distribution	Unattended	138.00	34.00		60	1
302	595-PLEASANT HILL	Distribution	Unattended	138.00	12.50		160	4
303	141-PLEASANT VALLEY	Transmission	Unattended	345.00	138.00	34.00	300	1
304	80-PONTIAC MIDPOINT-1	Transmission	Unattended	345.00	138.00	34.00	450	2
305	80-PONTIAC MIDPOINT-2	Distribution	Unattended	138.00	34.00	12.50	180	3
306	235-POPLAR CREEK	Distribution	Unattended	138.00	12.50		80	2
307	117-PROSPECT HEIGHTS-1	Transmission	Unattended	345.00	138.00	34.00	600	2
308	117-PROSPECT HEIGHTS-2	Distribution	Unattended	138.00	12.50		120	3
309	217-PROSPECT HTS	Distribution	Unattended	138.00	12.50		80	2
310	192-RIDGELAND	Distribution	Unattended	138.00	69.00	12.50	600	6
311	414-ROBERTS ROAD	Distribution	Unattended	138.00	12.50		80	2
312	439-ROCKDALE	Distribution	Unattended	138.00	12.50		80	2
313	133-ROCK FALLS-1	Distribution	Unattended	138.00	34.00	12.50	80	2
314	206-ROLLING MEADOWS	Distribution	Unattended	138.00	12.50		160	4
315	411-ROMEOVILLE	Distribution	Unattended	138.00	12.50		80	2
316	163-ROSCOE BERT-1	Distribution	Unattended	138.00	69.00	12.50	50	1
317	163-ROSCOE BERT-2	Distribution	Unattended	138.00	12.50		120	3
318	42-ROUND LAKE-1	Distribution	Unattended	138.00	34.00	12.50	120	2
319	42-ROUND LAKE-2	Distribution	Unattended	138.00	12.50		80	2
320	251-ROUND LAKE BEACH	Distribution	Unattended	138.00	12.50		80	2
321	194-SABROOKE-1	Distribution	Attended	138.00	69.00	12.50	150	2
322	194-SABROOKE-2	Distribution	Attended	138.00	12.50		80	2
323	164-SAND PARK	Distribution	Unattended	138.00	12.50		80	2
324	447-SANDRIDGE	Distribution	Unattended	138.00	12.50		40	2
325	146-SANDWICH	Distribution	Unattended	138.00	34.00	12.50	80	2
326	517-SAYRE	Distribution	Unattended	138.00	12.50		80	2
327	220-SOUTH SCHAUMBURG	Distribution	Unattended	138.00	12.50		120	3
328	253-SCHAUMBURG	Distribution	Unattended	138.00	12.50		160	4
329	431-SHOREWOOD	Distribution	Unattended	138.00	12.50		160	4
330	138-SILVER LAKE	Transmission	Unattended	345.00	138.00	34.00	600	2
331	85-SKOKIE-1	Distribution	Unattended	138.00	34.00	12.50	120	3
332	85-SKOKIE-2	Distribution	Unattended	138.00	12.50		140	4
333	88-SKOKIE-1	Transmission	Unattended	345.00	138.00	34.00	1200	4
334	88-SKOKIE-2	Distribution	Unattended	138.00	34.00	12.50	120	3
335	88-SKOKIE-3	Distribution	Unattended	138.00	12.50		106	3
336	577-SOUTH ELGIN-1	Distribution	Unattended	138.00	12.50		80	2
337	465-SOUTH HOLLAND	Distribution	Unattended	138.00	12.50		120	3
338	577-SOUTH ELGIN-2	Distribution	Unattended	138.00	34.00		120	2
339	390-SOUTH PECATONICA	Distribution	Unattended	138.00	12.50		10	1
340	79-SPAULDING-1	Distribution	Unattended	138.00	34.00	12.50	160	3
341	79-SPAULDING-2	Distribution	Unattended	138.00	12.50		80	2
342	372-STERLING	Distribution	Unattended	138.00	12.50		60	2
343	176-STILLMAN VALLEY	Distribution	Unattended	138.00	34.00	12.50	80	2
344	61-STREATOR	Distribution	Unattended	138.00	34.00	12.50	80	2
345	569-SUGAR GROVE-2	Distribution	Unattended	138.00	34.00	12.50	60	1
346	419-TINLEY PARK	Distribution	Unattended	138.00	12.50		160	4
347	185-TOLLWAY	Transmission	Unattended	345.00	138.00	34.00	300	1
348	207-TONNE-1	Distribution	Unattended	138.00	12.50		160	4
349	207-TONNE-2	Distribution	Unattended	138.00	34.00	12.50	120	2
350	539-WARRENVILLE	Distribution	Unattended	138.00	12.50		120	3
351	113-WATERMAN	Distribution	Unattended	138.00	34.00	4.00	40	1
352	16-WAUKEGAN-1	Transmission	Unattended	345.00	138.00	34.00	600	2
353	16-WAUKEGAN-2	Distribution	Attended	138.00	34.00	12.50	160	4
354	16-WAUKEGAN-3	Distribution	Attended	138.00	12.50		40	2
355	144-WAYNE	Transmission	Unattended	345.00	138.00	34.00	600	2
356	499-WEBER	Distribution	Unattended	138.00	12.50		80	2
357	171-WEMPLETOWN	Transmission	Unattended	345.00	138.00	34.00	300	1
358	131-WEST CHICAGO-1	Distribution	Unattended	138.00	34.00	12.50	160	4
359	131-WEST CHICAGO-2	Distribution	Unattended	138.00	12.50		120	3
360	375-WEST DEKALB	Distribution	Unattended	138.00	12.50		80	2
361	205-WHEELING	Distribution	Unattended	138.00	12.50		80	2
362	18-WILL COUNTY	Distribution	Attended	138.00	34.00	12.50	120	2
363	593-WILLOW SPRINGS	Distribution	Unattended	138.00	12.50		80	2
364	149-WILMINGTON-1	Distribution	Unattended	138.00	34.00	12.00	120	3
365	480-VETERANS	Distribution	Unattended	138.00	12.50		80	2
366	149-WILMINGTON-2	Distribution	Unattended	138.00	12.50		40	1
367	228-WILSON ROAD	Distribution	Unattended	138.00	12.50		120	3
368	112-WILTON CENTER	Transmission	Unattended	765.00	345.00	34.00	2000	6
369	143-WOLFS CROSSING	Transmission	Unattended	345.00	138.00	34.00	300	1
370	453-WOODHILL	Distribution	Unattended	138.00	12.50		113	3
371	559-WOODRIDGE	Distribution	Unattended	138.00	12.50		80	2
372	151-WOODSTOCK	Distribution	Unattended	138.00	12.50		120	3
373	145-YORK CENTER	Distribution	Unattended	138.00	12.50		240	6
374	282 ZION	Distribution	Unattended	138.00	12.50		40	2
375	184-ELK GROVE	Distribution	Unattended	138.00	34.00		120	2
376	GENERAL WAREHOUSE
377	TECHNICAL CENTER
378	E28-ALGONQUIN	Distribution	Unattended	34.00	12.50		28	3
379	513-AURORA-1	Distribution	Unattended	34.00	12.50		31	4
380	513-AURORA-2	Distribution	Unattended	34.00	4.00		13	2
381	W16-AURORA (INDIAN TRAIL)	Distribution	Unattended	34.00	12.50		16	2
382	W73-BALD MOUND	Distribution	Unattended	34.00	12.50		18	2
383	115-BEDFORD PARK	Distribution	Unattended	34.00	12.50		16	2
384	64-BELLWOOD	Distribution	Unattended	34.00	4.00		11	2
385	B20-BELVIDERE	Distribution	Unattended	34.00	12.50		28	3
386	556-BERWYN-2	Distribution	Unattended	12.50	4.00		16	2
387	W26-BIG TIMBER	Distribution	Unattended	34.00	12.50		28	3
388	W16-BLACKBERRY TWP	Distribution	Unattended	34.00	12.50		16	2
389	J69-BRAIDWOOD	Distribution	Unattended	34.00	12.50		25	3
390	W119-BRISTOL TWP	Distribution	Unattended	34.00	12.50		16	2
391	E24-CARY	Distribution	Unattended	34.00	12.50		19	2
392	K19-CEMETARY RD	Distribution	Unattended	34.00	12.50		22	3
393	B31-CHEMUNG	Distribution	Unattended	34.00	12.50		16	2
394	F96-CHICAGO HEIGHTS	Distribution	Unattended	34.00	12.50		12	2
395	59-CICERO-2	Distribution	Unattended	12.50	4.00		20	2
396	S37-BRUCE TWP	Distribution	Unattended	34.00	12.50		12	2
397	W384-BUTTERFIELD-1	Distribution	Unattended	34.00	12.50		10	1
398	B29-BYRON	Distribution	Unattended	34.00	12.50		25	3
399	J68-COAL CITY	Distribution	Unattended	34.00	12.50		19	2
400	F45-CRETE	Distribution	Unattended	34.00	12.50		19	2
401	E77-CRYSTAL LAKE	Distribution	Unattended	34.00	12.50		28	3
402	W50-DEERPATH	Distribution	Unattended	34.00	12.50		25	3
403	H78-DIXON	Distribution	Unattended	34.00	12.50		12	2
404	E71-DORR TWP-1	Distribution	Unattended	34.00	12.50		16	2
405	W38-DOWNERS GROVE TW	Distribution	Unattended	34.00	12.50		19	2
406	A94-DRUCE LAKE	Distribution	Unattended	34.00	12.50		16	2
407	462-DWIGHT	Distribution	Unattended	34.00	12.50		18	2
408	J40 - WESTERN AVE	Distribution	Unattended	34.00	12.50		18	2
409	J46-KAVANAUGH	Distribution	Unattended	34.00	12.50		18	2
410	A71-GRASS LAKE	Distribution	Unattended	34.00	12.50		22	3
411	B12-CAPRON	Distribution	Unattended	34.00	12.00		16	2
412	J15-ELWOOD	Distribution	Unattended	34.00	12.50		19	2
413	C20-EVANSTON	Distribution	Unattended	34.00	12.50		16	2
414	B32-GARDEN PRAIRIE	Distribution	Unattended	34.00	12.50		19	2
415	J49-GOUGAR ROAD	Distribution	Unattended	34.00	12.50		18	2
416	C93-HIGHLAND PARK	Distribution	Unattended	34.00	4.00		11	2
417	W48-HINSDALE	Distribution	Unattended	34.00	12.50		18	2
418	J97-JACKSON ST. (JOLIET)	Distribution	Unattended	34.00	4.00		12	2
419	W118-KENDALL TWP	Distribution	Unattended	34.00	12.50		18	2
420	B15-KINGSTON	Distribution	Unattended	34.00	12.50		11	2
421	B52-LEAF RIVER	Distribution	Unattended	34.00	12.50		15	4
422	H52-LELAND	Distribution	Unattended	34.00	12.50		12	2
423	W20-LILY LAKE	Distribution	Unattended	34.00	12.50		19	2
424	J58-MANHATTAN	Distribution	Unattended	34.00	12.50		16	2
425	B90-MAPLE PARK	Distribution	Unattended	34.00	12.50		16	2
426	123-MARGENGO	Distribution	Unattended	34.00	12.50		19	2
427	W35-UDINA	Distribution	Unattended	34.00	12.50		19	2
428	B10-HARVARD	Distribution	Unattended	34.00	12.50		16	2
429	318-HARVARD	Distribution	Unattended	34.00	12.50		19	2
430	460-HARVEY-1	Distribution	Unattended	34.00	12.50		20	2
431	460-HARVEY-2	Distribution	Unattended	34.00	4.00		20	2
432	C3-HIGHLAND PARK-1	Distribution	Unattended	34.00	12.50		18	2
433	D62-HILLSIDE	Distribution	Unattended	34.00	12.50		19	2
434	H47-HINCKLEY	Distribution	Unattended	34.00	12.50		12	2
435	553-HINSDALE	Distribution	Unattended	34.00	12.50		13	2
436	C65-EVANSTON	Distribution	Unattended	34.00	4.00		12	2
437	C66-EVANSTON	Distribution	Unattended	34.00	12.50		18	2
438	A31-FOX LAKE	Distribution	Unattended	34.00	12.50		19	3
439	W10-FOX RIVER HEIGHTS	Distribution	Unattended	34.00	12.50		19	2
440	D13-FORESTVIEW	Distribution	Unattended	34.00	12.50		16	2
441	121-FREEPORT	Distribution	Unattended	34.00	4.00		19	2
442	H23-FULTON	Distribution	Unattended	34.00	12.50		12	2
443	514-GLEN ELLYN	Distribution	Unattended	34.00	4.00		12	2
444	W115-GLENWOOD PARK	Distribution	Unattended	34.00	12.50		19	2
445	A87-GRAYS LAKE	Distribution	Unattended	34.00	12.50		19	2
446	B16-HAMPSHIRE	Distribution	Unattended	34.00	12.50		28	3
447	D351-HODGINS	Distribution	Unattended	34.00	12.50		16	2
448	E18-HONEY LAKE	Distribution	Unattended	34.00	12.50		19	2
449	E35-HUNTLEY	Distribution	Unattended	34.00	12.50		19	2
450	E29-JOHNSBURG	Distribution	Unattended	34.00	12.50		28	2
451	E19-ISLAND LAKE	Distribution	Unattended	34.00	12.50		19	2
452	450-WASHINGTON ST. JOLIET	Distribution	Unattended	34.00	12.50		19	2
453	LAGRANGE
454	280-LAKE BLUFF	Distribution	Unattended	34.00	4.00		13	3
455	C30-LAKE FOREST	Distribution	Unattended	34.00	12.50		19	2
456	E26-LAKE IN THE HILLS	Distribution	Unattended	34.00	12.50		28	3
457	A47-LAKE VILLA	Distribution	Unattended	34.00	12.50		19	2
458	K34-LEHIGH	Distribution	Unattended	34.00	12.50		16	2
459	J92-LEMONT	Distribution	Unattended	34.00	12.50		12	2
460	A12-LIBERTYVILLE	Distribution	Unattended	34.00	12.50		18	2
461	C81-LINCOLNWOOD	Distribution	Unattended	34.00	4.00		12	2
462	F149-LYNWOOD	Distribution	Unattended	34.00	12.50		13	2
463	K20-MANTENO	Distribution	Unattended	34.00	12.50		18	2
464	B51-MARENGO	Distribution	Unattended	34.00	12.50		16	2
465	D53-MAYWOOD	Distribution	Unattended	12.50	4.00		13	2
466	D187-MAYWOOD-1	Distribution	Unattended	34.00	12.50		16	2
467	H39-MENDOTA	Distribution	Unattended	34.00	12.50		25	3
468	E16-MCHENRY	Distribution	Unattended	34.00	12.50		19	2
469	W336-MILTON TWP	Distribution	Unattended	34.00	12.50		19	2
470	K18-MOMENCE	Distribution	Unattended	34.00	12.50		19	2
471	422-MORRIS	Distribution	Unattended	34.00	12.50		18	2
472	H26-MORRISON	Distribution	Unattended	34.00	12.50		12	2
473	B30-MT MORRIS	Distribution	Unattended	34.00	12.50		16	2
474	E8-NERGE	Distribution	Unattended	34.00	12.50		16	2
475	W71-NORTH AURORA	Distribution	Unattended	34.00	12.50		19	2
476	69-NORTH CHICAGO-2	Distribution	Unattended	34.00	12.50		19	2
477	A24-NORTH CHICAGO	Distribution	Unattended	34.00	12.50		19	2
478	D46-NORTHLAKE	Distribution	Unattended	34.00	12.50		19	2
479	D177-O'HARE FIELD	Distribution	Unattended	34.00	12.50		13	2
480	D179-O'HARE FIELD	Distribution	Unattended	34.00	12.50		19	3
481	D180-O'HARE FIELD	Distribution	Unattended	34.00	12.50		22	3
482	505-OAK PARK	Distribution	Unattended	12.50	4.00		18	3
483	S43-ODELL	Distribution	Unattended	34.00	12.50		16	2
484	W18-ORCHARD RD	Distribution	Unattended	34.00	12.50		16	2
485	B53-OREGON	Distribution	Unattended	34.00	12.50		18	2
486	E12-PALATINE	Distribution	Unattended	34.00	12.50		19	2
487	C55-PARK RIDGE	Distribution	Unattended	34.00	4.00		13	2
488	F17-PEOTONE	Distribution	Unattended	34.00	12.50		19	2
489	W25-PINGREE GROVE	Distribution	Unattended	34.00	12.50		16	2
490	J31-PLAINFIELD	Distribution	Unattended	34.00	12.50		19	2
491	H65-PLANO	Distribution	Unattended	34.00	12.50		17	2
492	W211-PLATO CENTER	Distribution	Unattended	34.00	12.50		16	2
493	B36-POLO	Distribution	Unattended	34.00	12.50		16	2
494	S66-PONTIAC-1	Distribution	Unattended	34.00	12.50		16	2
495	471-PONTIAC	Distribution	Unattended	34.00	12.50		19	2
496	B11-POPLAR GROVE	Distribution	Unattended	34.00	12.50		19	2
497	W51-RANDALL ROAD	Distribution	Unattended	34.00	12.50		25	3
498	E82-RICHMOND	Distribution	Unattended	34.00	12.50		19	2
499	J28-RIDGE ROAD	Distribution	Unattended	34.00	12.50		18	2
500	B55-ROCK CITY	Distribution	Unattended	34.00	12.50		13	2
501	E69-ROLLING MEADOWS	Distribution	Unattended	34.00	12.50		28	3
502	A67-RONDOUT	Distribution	Unattended	34.00	12.50		25	3
503	W236-ROSELLE	Distribution	Unattended	34.00	12.50		19	2
504	H60-SANDWICH	Distribution	Unattended	34.00	12.50		16	2
505	H14-SANDWICH	Distribution	Unattended	34.00	12.50		28	3
506	F12-SAUK TRAIL	Distribution	Unattended	34.00	12.50		19	2
507	D63-SCHILLER PARK	Distribution	Unattended	34.00	12.50		25	3
508	C77-SKOKIE	Distribution	Unattended	34.00	4.00		13	2
509	85-SKOKIE	Distribution	Unattended	34.00	4.00		11	2
510	88-SKOKIE	Distribution	Unattended	34.00	4.00		13	2
511	H53-SOMONAUK	Distribution	Unattended	34.00	12.50		19	2
512	E79-SOUTH WONDERLAKE	Distribution	Unattended	34.00	12.50		16	2
513	E20-SPRING GROVE	Distribution	Unattended	34.00	12.50		28	3
514	H25-STERLING	Distribution	Unattended	34.00	12.50		16	2
515	S61-STREATOR	Distribution	Unattended	34.00	4.00		13	2
516	S44-STREATOR	Distribution	Unattended	34.00	12.50		16	2
517	H70-SUBLETTE	Distribution	Unattended	34.00	12.50		14	2
518	D40-SUMMIT	Distribution	Unattended	34.00	12.50		16	2
519	316-SYCAMORE	Distribution	Unattended	34.00	12.50		44	5
520	J17-TROY TWP	Distribution	Unattended	34.00	12.50		19	2
521	459-VOLLMER ROAD-1	Distribution	Unattended	34.00	12.50		25	4
522	W39-WASCO	Distribution	Unattended	34.00	12.50		28	3
523	E11-WAUCONDA	Distribution	Unattended	34.00	12.50		25	3
524	E22-WAUCONDA	Distribution	Unattended	34.00	12.50		25	3
525	A41-WAUKEGAN-2	Distribution	Unattended	34.00	4.00		13	2
526	A68-WAUKEGAN	Distribution	Unattended	34.00	12.50		16	2
527	A70-WAUKEGAN	Distribution	Unattended	34.00	12.50		25	3
528	W33-WAYNE	Distribution	Unattended	34.00	12.50		19	2
529	558-WESTMONT-1	Distribution	Unattended	34.00	12.50		31	4
530	W30-WHEATON	Distribution	Unattended	34.00	12.50		19	2
531	249-WILMETTE-1	Distribution	Unattended	34.00	12.50		34	4
532	249-WILMETTE-2	Distribution	Unattended	34.00	4.00		16	2
533	B95-SOUTH DEKALB	Distribution	Unattended	34.00	12.50		18	2
534	W29-WINFIELD TWP	Distribution	Unattended	34.00	12.50		13	2
535	E17-WONDER LAKE	Distribution	Unattended	34.00	12.50		16	2
536	G78-WORTH	Distribution	Unattended	34.00	12.50		16	2
537	A82-ZION	Distribution	Unattended	34.00	12.50		13	2
538	C23-SEARLE	Distribution	Unattended	34.00	12.50		19	2
539	A91-ZION	Distribution	Unattended	34.00	12.50		16	2
540	J25- JACKSON TWP.	Distribution	Unattended	34.00	12.50		18	2
541	W148-AURORA TWP	Distribution	Unattended	34.00	12.50		16	2
542	OUTSIDE CHICAGO (UNDER 10MVA)
543	W348-BENSENVILLE-1	Distribution	Unattended	34.00	12.50		9	1
544	W348-BENSENVILLE-2	Distribution	Unattended	34.00	4.00		3	1
545	D69-BROADVIEW-1	Distribution	Unattended	34.00	12.50		6	1
546	D69-BROADVIEW-2	Distribution	Unattended	34.00	4.00		5	1
547	W218-CARPENTERSVILLE-1	Distribution	Unattended	34.00	12.50		9	1
548	W218-CARPENTERSVILLE-2	Distribution	Unattended	34.00	4.00		5	1
549	E71-DORR TWP-2	Distribution	Unattended	34.00	4.00		3	1
550	B45-LENA	Distribution	Unattended	34.00	12.50		6	1
551	J16-EASTERN AVE (JOLIET)-1	Distribution	Unattended	34.00	12.50		6	1
552	J16-EASTERN AVE (JOLIET)-2	Distribution	Unattended	34.00	4.00		6	1
553	501-ELMHURST-1	Distribution	Unattended	34.00	12.50		6	1
554	501-ELMHURST-2	Distribution	Unattended	34.00	4.00		8	2
555	W345-ELMHURST-1	Distribution	Unattended	34.00	12.50		9	1
556	W345-ELMHURST-2	Distribution	Unattended	34.00	4.00		6	1
557	C53-EVANSTON-1	Distribution	Unattended	34.00	12.50		9	1
558	C53-EVANSTON-2	Distribution	Unattended	34.00	4.00		6	1
559	D99-FRANKLIN PARK-1	Distribution	Unattended	34.00	12.50		6	1
560	D99-FRANKLIN PARK-2	Distribution	Unattended	34.00	4.00		6	1
561	B17-GENOA-1	Distribution	Unattended	34.00	12.50		9	1
562	B17-GENOA-2	Distribution	Unattended	34.00	4.00		3	1
563	C62-GLENCOE-1	Distribution	Unattended	34.00	4.00		5	1
564	C62-GLENCOE-2	Distribution	Unattended	12.50	4.00		6	1
565	C3-HIGHLAND PARK-2	Distribution	Unattended	34.00	4.00		3	1
566	G88-HOMETOWN-1	Distribution	Unattended	34.00	12.50		6	1
567	G88-HOMETOWN-2	Distribution	Unattended	34.00	4.00		6	1
568	D16-LAGRANGE HIGHLANDS-1	Distribution	Unattended	34.00	12.50		9	1
569	D16-LAGRANGE HIGHLANDS-2	Distribution	Unattended	34.00	4.00		6	1
570	D87-LEYDEN TWP-1	Distribution	Unattended	34.00	12.50		9	1
571	D87-LEYDEN TWP-2	Distribution	Unattended	34.00	4.00		6	1
572	D 229-LYONS TWP-1	Distribution	Unattended	34.00	12.50		6	1
573	D 229-LYONS TWP-2	Distribution	Unattended	34.00	4.00		6	1
574	D187-MAYWOOD-2	Distribution	Unattended	34.00	4.00		6	1
575	D20-MELROSE PARK-1	Distribution	Unattended	34.00	12.50		9	1
576	D20-MELROSE PARK-2	Distribution	Unattended	34.00	4.00		9	1
577	311-MENDOTA-1	Distribution	Unattended	34.00	12.50		6	1
578	311-MENDOTA-2	Distribution	Unattended	34.00	4.00		9	2
579	C33-NILES-1	Distribution	Unattended	34.00	12.50		6	1
580	C33-NILES-2	Distribution	Unattended	34.00	4.00		6	1
581	C19-PARK RIDGE-1	Distribution	Unattended	34.00	4.00		5	3
582	C19-PARK RIDGE-2	Distribution	Unattended	34.00	12.50		9	1
583	S66-PONTIAC-2	Distribution	Unattended	34.00	4.00		8	2
584	D133-RIVER GROVE-1	Distribution	Unattended	34.00	12.50		9	1
585	D133-RIVER GROVE-2	Distribution	Unattended	34.00	4.00		5	1
586	D175-SCHILLER PARK-1	Distribution	Unattended	34.00	4.00		6	1
587	D175-SCHILLER PARK-2	Distribution	Unattended	34.00	12.50		9	1
588	J12-BREEN ROAD	Distribution	Unattended	34.00	12.50		9	1
589	H62-STERLING-1	Distribution	Unattended	34.00	12.50		6	1
590	H62-STERLING-2	Distribution	Unattended	34.00	4.00		5	1
591	C73-TECHNY-1	Distribution	Unattended	34.00	12.50		9	1
592	C73-TECHNY-2	Distribution	Unattended	34.00	4.00		3	1
593	C96-TECHNY SOUTH	Distribution	Unattended	34.00	12.50		9	1
594	W334-VILLA PARK-1	Distribution	Unattended	34.00	12.50		6	1
595	W334-VILLA PARK-2	Distribution	Unattended	34.00	4.00		6	1
596	459-VOLLMER ROAD-2	Distribution	Unattended	34.00	4.00		3	1
597	A41-WAUKEGAN-1	Distribution	Unattended	34.00	12.50		6	1
598	A43-WAUKEGAN-1	Distribution	Unattended	34.00	12.50		6	1
599	A43-WAUKEGAN-2	Distribution	Unattended	34.00	4.00		9	1
600	B49-KENT	Distribution	Unattended	34.00	12.50		9	1
601	G42-WORTH-1	Distribution	Unattended	34.00	12.50		9	1
602	G42-WORTH-2	Distribution	Unattended	34.00	4.00		3	1
603	558-WESTMONT-2	Distribution	Unattended	34.00	4.00		6	1
604	R19-ACORN	Distribution	Unattended	12.50	4.00		5	1
605	W346-ADDISON TWP	Distribution	Unattended	34.00	12.50		6	1
606	B89-AFTON	Distribution	Unattended	34.00	12.50		5	1
607	H67-AMBOY	Distribution	Unattended	34.00	12.50		6	1
608	H43-AMBOY (GREEN RIVER)	Distribution	Unattended	34.00	12.50		6	1
609	E27-ARLINGTON HEIGHTS	Distribution	Unattended	34.00	4.00		3	1
610	E39-ARLINGTON HEIGHTS	Distribution	Unattended	34.00	4.00		3	1
611	E70-ARLINGTON HEIGHTS	Distribution	Unattended	34.00	4.00		5	1
612	E81-ARLINGTON HEIGHTS	Distribution	Unattended	34.00	4.00		6	1
613	K32-AROMA PARK	Distribution	Unattended	34.00	12.50		6	1
614	H49-ASHTON	Distribution	Unattended	34.00	12.50		6	1
615	W114-AURORA (ILLINOIS AVE)	Distribution	Unattended	34.00	4.00		3	1
616	W148-AURORA TWP-1	Distribution	Unattended	34.00	12.50		16	2
617	W152-AURORA (KENSINGTON)	Distribution	Unattended	34.00	12.50		6	1
618	J21-AUX SABLE TWP	Distribution	Unattended	34.00	12.50		9	1
619	B39-BAILEYVILLE	Distribution	Unattended	34.00	12.50		9	1
620	W233-BARTLETT	Distribution	Unattended	34.00	12.50		9	1
621	A57-BEACH	Distribution	Unattended	34.00	12.50		6	1
622	R23-BEATTIE	Distribution	Unattended	12.50	4.00		5	1
623	F16-BEECHER	Distribution	Unattended	34.00	12.50		9	1
624	J81-BELLE AV	Distribution	Unattended	34.00	4.00		3	1
625	D12-BELLWOOD	Distribution	Unattended	34.00	4.00		6	1
626	B19-BELVIDERE-1	Distribution	Unattended	34.00	4.00		5	1
627	W349-BENSENVILLE	Distribution	Unattended	34.00	4.00		6	2
628	D86-BERKELEY	Distribution	Unattended	34.00	4.00		6	1
629	D34-BERWYN	Distribution	Unattended	12.50	4.00		6	1
630	S26-BLACKSTONE	Distribution	Unattended	34.00	12.50		3	1
631	J53-BLODGETT RD	Distribution	Unattended	34.00	12.50		9	1
632	F122-BLOOM TWP-1	Distribution	Unattended	34.00	12.50		9	1
633	F122-BLOOM TWP-2	Distribution	Unattended	34.00	4.00		3	1
634	F79-BLOOM TWP	Distribution	Unattended	34.00	4.00		9	1
635	G16-BLUE ISLAND	Distribution	Unattended	34.00	4.00		8	1
636	G64-BLUE ISLAND	Distribution	Unattended	34.00	4.00		3	1
637	G81-BLUE ISLAND	Distribution	Unattended	34.00	4.00		3	1
638	B19-BELVIDERE-2	Distribution	Unattended	34.00	12.50		9	1
639	J88-BLUFF ST (JOLIET)	Distribution	Unattended	34.00	4.00		5	1
640	K40-BOURBONNAIS TWP	Distribution	Unattended	34.00	12.50		9	1
641	K29-BRADLEY	Distribution	Unattended	34.00	4.00		5	1
642	C34-BRAESIDE	Distribution	Unattended	34.00	12.50		6	1
643	D242-BRIDGEVIEW	Distribution	Unattended	34.00	12.50		6	1
644	D47-BROADVIEW-1	Distribution	Unattended	34.00	12.50		6	1
645	D47-BROADVIEW-2	Distribution	Unattended	34.00	4.00		3	1
646	D80-BROADVIEW	Distribution	Unattended	34.00	12.50		9	1
647	J55-BROADWAY ST	Distribution	Unattended	34.00	4.00		3	1
648	D115-BROOKFIELD	Distribution	Unattended	34.00	4.00		6	1
649	D140-BROOKFIELD	Distribution	Unattended	34.00	4.00		6	1
650	E46-BURTON BRIDGE	Distribution	Unattended	34.00	12.50		9	1
651	G30-CALUMET CITY	Distribution	Unattended	34.00	4.00		3	1
652	G100-CALUMET CITY	Distribution	Unattended	34.00	4.00		5	1
653	B47-CEDARVILLE	Distribution	Unattended	34.00	12.50		6	1
654	D11-CENTERPOINT	Distribution	Unattended	34.00	12.50		9	1
655	J67-CHANNAHON	Distribution	Unattended	34.00	12.50		3	1
656	B50-CHERRY GROVE	Distribution	Unattended	34.00	12.50		8	1
657	J84-CHERRY ST (JOLIET)	Distribution	Unattended	34.00	4.00		5	1
658	F91-CHICAGO HEIGHTS	Distribution	Unattended	34.00	4.00		3	1
659	F73-CHICAGO HEIGHTS	Distribution	Unattended	34.00	12.50		6	1
660	D15-CICERO	Distribution	Unattended	12.50	4.00		7	1
661	D100-CICERO	Distribution	Unattended	12.50	4.00		6	1
662	D151-CICERO	Distribution	Unattended	12.50	4.00		6	1
663	D217-CICERO	Distribution	Unattended	12.50	4.00		5	1
664	B86-CLARE	Distribution	Unattended	34.00	12.50		6	1
665	B35-COLETA	Distribution	Unattended	34.00	12.50		5	1
666	S42-CORNELL	Distribution	Unattended	34.00	12.50		3	1
667	D44-COUNTRYSIDE	Distribution	Unattended	34.00	12.50		9	1
668	B26-DAVIS JUNCTION	Distribution	Unattended	34.00	12.50		9	1
669	H51-INDIAN CREEK	Distribution	Unattended	34.00	12.50		9	1
670	J48-BRANDON ROAD	Distribution	Unattended	34.00	12.50		9	1
671	C51-DESPLAINES	Distribution	Unattended	34.00	4.00		6	1
672	C79-DESPLAINES	Distribution	Unattended	34.00	4.00		6	1
673	G126-DOLTON	Distribution	Unattended	34.00	4.00		6	1
674	W41-DOWNERS GROVE	Distribution	Unattended	34.00	12.50		9	1
675	G909-DOLTON-1	Distribution	Unattended	34.00	12.50		9	1
676	G909-DOLTON-2	Distribution	Unattended	34.00	12.50		9	1
677	W384-BUTTERFIELD-2	Distribution	Unattended	34.00	12.50		9	1
678	W43-DOWNERS GROVE	Distribution	Unattended	34.00	4.00		6	1
679	J76-DUPONT RD	Distribution	Unattended	34.00	12.50		9	1
680	H50-EARLVILLE	Distribution	Unattended	34.00	12.50		6	1
681	K42-EAST KANKAKEE	Distribution	Unattended	34.00	12.50		6	1
682	B54-EAST OREGON	Distribution	Unattended	34.00	12.50		6	1
683	S48-EAST STREATOR	Distribution	Unattended	34.00	12.50		9	1
684	R26-EIGHTEENTH AVE	Distribution	Unattended	12.50	4.00		5	1
685	W13-ELDAMAIN	Distribution	Unattended	34.00	12.50		9	1
686	W202-ELGIN	Distribution	Unattended	34.00	12.50		9	1
687	W209-ELGIN	Distribution	Unattended	34.00	4.00		5	1
688	W342-ELMHURST	Distribution	Unattended	34.00	4.00		6	1
689	W343-ELMHURST-1	Distribution	Unattended	34.00	12.50		6	1
690	W343-ELMHURST-2	Distribution	Unattended	34.00	4.00		3	1
691	D111-ELMWOOD PARK	Distribution	Unattended	12.50	4.00		6	1
692	D149-ELMWOOD PARK	Distribution	Unattended	12.50	4.00		6	1
693	D173-ELMWOOD PARK	Distribution	Unattended	12.50	4.00		7	1
694	S41-EPPARDS POINT	Distribution	Unattended	34.00	12.50		4	1
695	C41-EVANSTON	Distribution	Unattended	34.00	4.00		9	1
696	C43-EVANSTON	Distribution	Unattended	34.00	4.00		6	1
697	C54-EVANSTON	Distribution	Unattended	34.00	12.50		9	1
698	C75-EVANSTON	Distribution	Unattended	34.00	4.00		6	1
699	C83-EVANSTON	Distribution	Unattended	34.00	12.50		9	1
700	G69-EVERGREEN PARK	Distribution	Unattended	34.00	4.00		6	1
701	G82-EVERGREEN PARK	Distribution	Unattended	34.00	4.00		6	1
702	K39-EXLINE ROAD	Distribution	Unattended	34.00	12.50		6	1
703	W102-FABYAN	Distribution	Unattended	34.00	12.50		6	1
704	D255-FORESTVIEW	Distribution	Unattended	34.00	12.50		9	1
705	B37-FORRESTON	Distribution	Unattended	34.00	12.50		5	1
706	R35-FOURTEENTH ST.	Distribution	Unattended	12.50	4.00		5	1
707	R24-FOURTH AVE.	Distribution	Unattended	34.00	4.00		5	1
708	E72-FOX RIVER GROVE	Distribution	Unattended	34.00	4.00		9	1
709	B64-FRANKLIN GROVE	Distribution	Unattended	34.00	12.50		6	1
710	B56-FREEPORT	Distribution	Unattended	34.00	4.00		3	1
711	A50-GAGES LAKE	Distribution	Unattended	34.00	12.50		6	1
712	H27-GALT	Distribution	Unattended	34.00	12.50		6	1
713	132-GARDEN PLAIN-2	Distribution	Unattended	34.00	12.50		6	1
714	S63-GARDNER	Distribution	Unattended	34.00	12.50		9	1
715	C61-GARNETT	Distribution	Unattended	34.00	12.50		9	1
716	W330-GLEN ELLYN	Distribution	Unattended	34.00	4.00		3	1
717	C92-GLENCOE	Distribution	Unattended	34.00	4.00		5	1
718	C7-GLENVIEW	Distribution	Unattended	34.00	4.00		5	1
719	C25-GLENVIEW	Distribution	Unattended	34.00	12.50		9	1
720	C80-GLENVIEW	Distribution	Unattended	34.00	12.50		9	1
721	C95-GLENVIEW	Distribution	Unattended	34.00	4.00		6	1
722	F36-GOODENOW	Distribution	Unattended	34.00	12.50		9	1
723	J66-GOOSE LAKE	Distribution	Unattended	34.00	12.50		6	1
724	S25-GRAND RAPIDS	Distribution	Unattended	34.00	12.50		6	1
725	S29-GRAND RIDGE	Distribution	Unattended	34.00	12.50		6	1
726	K44-GRANT PARK	Distribution	Unattended	34.00	12.50		6	1
727	A81-GREAT LAKES	Distribution	Unattended	34.00	12.50		6	1
728	E59-HAEGER'S CORNER	Distribution	Unattended	34.00	12.50		9	1
729	E21-HARTLAND	Distribution	Unattended	34.00	12.50		6	1
730	B14-HARVARD	Distribution	Unattended	34.00	4.00		3	1
731	G83-HARVEY	Distribution	Unattended	34.00	4.00		3	1
732	G113-HARVEY	Distribution	Unattended	34.00	4.00		6	1
733	B23-HERBERT	Distribution	Unattended	34.00	4.00		1	1
734	C82-HIGHLAND PARK	Distribution	Unattended	34.00	4.00		5	1
735	J62-HOMER TWP	Distribution	Unattended	34.00	12.50		9	1
736	F24-HOMEWOOD	Distribution	Unattended	34.00	4.00		6	2
737	F75-HOMEWOOD	Distribution	Unattended	34.00	4.00		3	1
738	H38-HOOPHOLE	Distribution	Unattended	34.00	12.50		4	1
739	J32-KAHLER RD	Distribution	Unattended	34.00	12.50		6	1
740	K23-KANKAKEE	Distribution	Unattended	34.00	4.00		4	1
741	K33-KANKAKEE	Distribution	Unattended	34.00	12.50		6	1
742	S14-KERNAN	Distribution	Unattended	34.00	12.50		1	1
743	B40-KETCHUM	Distribution	Unattended	34.00	12.50		9	1
744	B28-KIRKLAND	Distribution	Unattended	34.00	12.50		6	2
745	D172-LAGRANGE	Distribution	Unattended	34.00	4.00		6	1
746	D125-LAGRANGE PARK	Distribution	Unattended	34.00	4.00		6	1
747	C76-LAKE FOREST	Distribution	Unattended	34.00	4.00		6	2
748	B63-LANARK	Distribution	Unattended	34.00	12.50		9	1
749	H57-LEE	Distribution	Unattended	34.00	12.50		3	1
750	J87-LEMONT	Distribution	Unattended	34.00	12.50		9	1
751	D45-LEYDEN TWP	Distribution	Unattended	34.00	4.00		6	1
752	D67-LEYDEN TWP	Distribution	Unattended	34.00	12.50		6	1
753	D267-LEYDEN TWP	Distribution	Unattended	34.00	4.00		6	1
754	A64-LIBERTYVILLE	Distribution	Unattended	34.00	4.00		3	1
755	C22-LINCOLNWOOD	Distribution	Unattended	34.00	4.00		9	2
756	J24-LISBON	Distribution	Unattended	34.00	12.50		6	1
757	W44-LISLE	Distribution	Unattended	34.00	12.50		6	1
758	J18-LOCKPORT	Distribution	Unattended	34.00	12.50		9	1
759	S40-LODEMIA	Distribution	Unattended	34.00	12.50		3	1
760	120-LOMBARD	Distribution	Unattended	34.00	12.50		3	1
761	W52-LOMBARD	Distribution	Unattended	34.00	4.00		5	3
762	W331-LOMBARD	Distribution	Unattended	34.00	4.00		3	1
763	S21-LOSTANT	Distribution	Unattended	34.00	12.50		6	1
764	S27-LOWELL	Distribution	Unattended	34.00	12.50		3	1
765	H28-LYNDON	Distribution	Unattended	34.00	12.50		6	1
766	D89-LYONS	Distribution	Unattended	34.00	4.00		5	1
767	S35-MANVILLE	Distribution	Unattended	34.00	12.50		3	1
768	G128-MARKHAM-1	Distribution	Unattended	34.00	12.50		6	1
769	G128-MARKHAM-2	Distribution	Unattended	34.00	4.00		3	1
770	D216-MAYWOOD	Distribution	Unattended	34.00	4.00		6	1
771	S67-MAZON	Distribution	Unattended	34.00	12.50		3	1
772	W216-MEADOWDALE	Distribution	Unattended	34.00	12.50		9	1
773	D201-MELROSE PARK	Distribution	Unattended	34.00	4.00		6	1
774	J38-MESSENGER WOODS	Distribution	Unattended	34.00	12.50		6	1
775	B46-MILLEDGEVILLE	Distribution	Unattended	34.00	12.50		6	1
776	W31-MILTON TWP-1	Distribution	Unattended	34.00	12.50		6	1
777	W31-MILTON TWP-2	Distribution	Unattended	34.00	4.00		3	1
778	S39-MINONK	Distribution	Unattended	34.00	12.50		9	1
779	J20-MISSISSIPPI	Distribution	Unattended	34.00	12.50		9	1
780	B25-MONROE CENTER	Distribution	Unattended	34.00	12.00		9	1
781	H29-MORRISON	Distribution	Unattended	34.00	4.00		4	1
782	C6-MORTON GROVE	Distribution	Unattended	34.00	4.00		6	1
783	C52-MORTON GROVE	Distribution	Unattended	34.00	4.00		5	1
784	C78-MORTON GROVE	Distribution	Unattended	34.00	4.00		6	2
785	C26-MT PROSPECT	Distribution	Unattended	34.00	4.00		6	2
786	A35-MUNDELEIN	Distribution	Unattended	34.00	4.00		3	1
787	W46-NAPERVILLE	Distribution	Unattended	34.00	12.50		6	1
788	J60-NEW LENOX	Distribution	Unattended	34.00	12.50		6	1
789	R14-NORTH	Distribution	Unattended	12.50	4.00		5	1
790	B96-NORTH HAMPSHIRE	Distribution	Unattended	34.00	12.50		9	1
791	C85-NORTHBROOK-1	Distribution	Unattended	34.00	4.00		6	1
792	D51-NORTHLAKE	Distribution	Unattended	34.00	4.00		3	1
793	K50-NORTH MOMENCE	Distribution	Unattended	34.00	12.50		9	1
794	G39-OAK LAWN	Distribution	Unattended	34.00	4.00		5	1
795	G66-OAK LAWN	Distribution	Unattended	34.00	4.00		6	1
796	G125-OAK LAWN	Distribution	Unattended	34.00	4.00		6	1
797	D204-OAK PARK	Distribution	Unattended	12.50	4.00		6	1
798	D292-OAK PARK	Distribution	Unattended	12.50	4.00		6	1
799	H44-OHIO	Distribution	Unattended	34.00	12.50		3	1
800	C21-OPTIMA	Distribution	Unattended	34.00	12.50		9	1
801	G99-PALOS HEIGHTS	Distribution	Unattended	34.00	12.50		6	1
802	F29-PARK FOREST	Distribution	Unattended	34.00	4.00		3	1
803	F41-PARK FOREST	Distribution	Unattended	34.00	4.00		3	1
804	F111-PARK FOREST	Distribution	Unattended	34.00	4.00		5	1
805	C36-PARK RIDGE	Distribution	Unattended	34.00	4.00		6	1
806	C87-PARK RIDGE	Distribution	Unattended	34.00	4.00		3	1
807	C85-NORTHBROOK-2	Distribution	Unattended	34.00	12.50		3	1
808	C97-PARK RIDGE	Distribution	Unattended	34.00	12.50		9	1
809	H59-PAW PAW	Distribution	Unattended	34.00	12.50		3	1
810	B42-PEARL CITY	Distribution	Unattended	34.00	12.50		5	1
811	H66-PLANO	Distribution	Unattended	34.00	12.50		9	1
812	H10-PRARIEVILLE	Distribution	Unattended	34.00	12.50		8	1
813	H91-PROPHETSTOWN	Distribution	Unattended	34.00	12.50		8	1
814	S12-RANSOM	Distribution	Unattended	34.00	12.50		8	1
815	B48-RINK	Distribution	Unattended	34.00	12.50		6	1
816	D143-RIVER FOREST	Distribution	Unattended	12.50	4.00		6	1
817	G31-RIVERDALE	Distribution	Unattended	34.00	4.00		3	1
818	D103-RIVERSIDE	Distribution	Unattended	12.50	4.00		6	1
819	D241-RIVERSIDE	Distribution	Unattended	34.00	4.00		6	1
820	133-ROCK FALLS-2	Distribution	Unattended	34.00	12.50		9	1
821	H41-ROCK FALLS	Distribution	Unattended	34.00	12.50		9	1
822	R18-ROCKTON AVE	Distribution	Unattended	12.50	4.00		5	1
823	A37-ROUND LAKE BEACH	Distribution	Unattended	34.00	12.50		9	1
824	S11-ROWE	Distribution	Unattended	34.00	12.50		2	1
825	S20-RUTLAND	Distribution	Unattended	34.00	12.50		9	1
826	J23-SARATOGA	Distribution	Unattended	34.00	12.50		9	1
827	J65-SENECA	Distribution	Unattended	34.00	12.50		6	1
828	H56-SHABBONA	Distribution	Unattended	34.00	12.50		3	1
829	E38-SILVER LAKE	Distribution	Unattended	34.00	12.50		6	1
830	C28-SKOKIE	Distribution	Unattended	34.00	4.00		6	1
831	C32-SKOKIE	Distribution	Unattended	34.00	4.00		6	1
832	C69-SKOKIE	Distribution	Unattended	34.00	4.00		6	1
833	C74-SKOKIE	Distribution	Unattended	34.00	4.00		6	1
834	C86-SKOKIE	Distribution	Unattended	34.00	4.00		6	1
835	C90-SKOKIE	Distribution	Unattended	34.00	4.00		6	1
836	C94-SKOKIE	Distribution	Unattended	34.00	4.00		6	1
837	H76-SOUTH DIXON	Distribution	Unattended	34.00	12.50		9	1
838	S47-SOUTH WILMINGTON	Distribution	Unattended	34.00	12.50		9	1
839	E10-SOUTH HUNTLEY	Distribution	Unattended	34.00	12.50		9	1
840	K45-ST.ANNE	Distribution	Unattended	34.00	12.50		6	1
841	K52-ST.GEORGE	Distribution	Unattended	34.00	12.50		9	1
842	F132-STEGER	Distribution	Unattended	34.00	4.00		3	1
843	H18-STERLING	Distribution	Unattended	34.00	12.50		5	1
844	312-STEWARD	Distribution	Unattended	34.00	12.50		3	1
845	D114-STICKNEY	Distribution	Unattended	34.00	12.50		6	1
846	D244-STICKNEY TWP	Distribution	Unattended	34.00	12.50		9	1
847	B27-STILLMAN VALLEY	Distribution	Unattended	34.00	12.50		6	1
848	B43-STOCKTON	Distribution	Unattended	34.00	12.50		6	1
849	D194-STONE PARK	Distribution	Unattended	34.00	4.00		6	1
850	R21-SUNSET	Distribution	Unattended	12.50	4.00		5	1
851	W28-SUNSET PARK	Distribution	Unattended	34.00	12.50		6	1
852	F115-THORNTON	Distribution	Unattended	34.00	4.00		3	1
853	G 19 TINLEY PARK	Distribution	Unattended	34.00	12.50		6	1
854	S15-TOLUCA	Distribution	Unattended	34.00	12.50		6	1
855	S19-TONICA	Distribution	Unattended	34.00	12.00		9	1
856	W64-TRI STATE-1	Distribution	Unattended	34.00	12.50		6	1
857	W64-TRI STATE-2	Distribution	Unattended	34.00	4.00		3	1
858	B57-UNION	Distribution	Unattended	34.00	12.50		9	1
859	S36-VERONA	Distribution	Unattended	34.00	12.50		3	1
860	W333-VILLA PARK	Distribution	Unattended	34.00	4.00		6	1
861	A27-WADSWORTH-1	Distribution	Unattended	34.00	12.50		6	1
862	A27-WADSWORTH-2	Distribution	Unattended	34.00	4.00		3	1
863	H40-WALNUT	Distribution	Unattended	34.00	12.50		6	1
864	K15-WARNER BRIDGE	Distribution	Unattended	34.00	12.50		6	1
865	A92-WARREN	Distribution	Unattended	34.00	4.00		1	1
866	B44-WARREN	Distribution	Unattended	34.00	12.50		8	1
867	J33-WASH ST (JOLIET)	Distribution	Unattended	34.00	12.50		9	1
868	H54-WATERMAN	Distribution	Unattended	34.00	12.50		6	1
869	H55-WATERMAN	Distribution	Unattended	34.00	4.00		2	1
870	E41-WAUCONDA	Distribution	Unattended	34.00	4.00		3	1
871	A49-WAUKEGAN	Distribution	Unattended	34.00	4.00		3	1
872	A56-WAUKEGAN	Distribution	Unattended	34.00	4.00		6	1
873	A61-WAUKEGAN-1	Distribution	Unattended	34.00	12.50		6	1
874	A61-WAUKEGAN-2	Distribution	Unattended	34.00	4.00		3	1
875	A63-WAUKEGAN	Distribution	Unattended	34.00	4.00		5	1
876	A65-WAUKEGAN	Distribution	Unattended	34.00	4.00		3	1
877	J13-WAUPONSEE	Distribution	Unattended	34.00	12.50		6	1
878	S16-WENONA-1	Distribution	Unattended	34.00	12.50		3	1
879	S16-WENONA-2	Distribution	Unattended	34.00	4.00		2	1
880	R22-WEST	Distribution	Unattended	12.50	4.00		5	1
881	W335-WEST CHICAGO-1	Distribution	Unattended	34.00	12.50		6	1
882	W335-WEST CHICAGO-2	Distribution	Unattended	34.00	4.00		3	1
883	W17-WEST SUGAR GROVE	Distribution	Unattended	34.00	12.50		9	1
884	D24-WESTERN SPRINGS	Distribution	Unattended	34.00	4.00		9	1
885	W340-WEISBROOK	Distribution	Unattended	34.00	12.50		9	1
886	W304-WHEATON	Distribution	Unattended	34.00	12.50		9	1
887	C31-WILMETTE	Distribution	Unattended	34.00	4.00		5	1
888	C56-WILMETTE	Distribution	Unattended	34.00	4.00		6	1
889	C89-WILMETTE	Distribution	Unattended	34.00	4.00		6	1
890	149-WILMINGTON	Distribution	Unattended	34.00	12.50		9	1
891	D17-WINSTON PARK	Distribution	Unattended	34.00	12.50		9	1
892	G121-WORTH	Distribution	Unattended	34.00	12.50		9	1
893	W354-YORK CENTER	Distribution	Unattended	34.00	12.50		7	1
894	H36-YORKTOWN	Distribution	Unattended	34.00	12.50		6	1
895	W12-YORKVILLE	Distribution	Unattended	34.00	4.00		9	1
896	J29-GORE ROAD	Distribution	Unattended	34.00	12.00		9	1
897	J45 - PINE BLUFF	Distribution	Unattended	34.00	12.50		9	1
898	J40 - WESTERN AVE - 2	Distribution	Unattended	34.00	12.50		18	2
899	A15-ZION	Distribution	Unattended	34.00	12.50		6	1
900	SPARE TRANSFORMER-1			765.00	345.00	34.00	666		4
901	SPARE TRANSFORMER-2			345.00	138.00	34.00	2352		7
902	SPARE TRANSFORMER-3			138.00	69.00		180		3
903	SPARE TRANSFORMER-4			138.00	69.00	12.50	467		7
904	SPARE TRANSFORMER-5			138.00	34.50		137		2
905	SPARE TRANSFORMER-6			138.00	34.50	13.20	653		11
906	SPARE TRANSFORMER-7			138.00	13.20		1990		38
907	SPARE TRANSFORMER-8			69.00	12.50		266		7
908	SPARE TRANSFORMER-9			34.00	13.20		229		36
909	SPARE TRANSFORMER-10			34.00	4.16		183		27
910	SPARE TRANSFORMER-11			12.50	4.16		192		41

GENERAL INFORMATION
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept. Caroline Fulginiti Vice President, Assistant Controller, Exelon 2 Lincoln Center, Oakbrook Terrace, Illinois 60181-4260
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized. State of Incorporation: IL Date of Incorporation: 1913-10-17 Incorporated Under Special Law:
3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased. Not applicable. (a) Name of Receiver or Trustee Holding Property of the Respondent: (b) Date Receiver took Possession of Respondent Property: (c) Authority by which the Receivership or Trusteeship was created: (d) Date when possession by receiver or trustee ceased:
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated. Electric utility services in the State of Illinois.
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements? (1) ☐ Yes (2) ☑ No

OFFICERS
Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made.
Line No.	OfficerTitle Title (a)	OfficerName Name of Officer (b)	OfficerSalary Salary for Year (c)	DateOfficerIncumbencyStarted Date Started in Period (d)	DateOfficerIncumbencyEnded Date Ended in Period (e)
1	President and Chief Executive Officer	Gil Quiniones	632,678
2	Executive Vice President and Chief Operating Officer	David Perez	420,000	2024-01-01
3	Senior Vice President, Chief Financial Officer and Treasurer	Joshua Levin	386,250
4	Senior Vice President, Governmental, Regulatory and External Affairs	Lewis Binswanger	412,412
5	Senior Vice President, Customer Operations and Strategic Initiatives	Melissa Washington	370,452
6	Senior Vice President and General Counsel	E. Glenn Rippie	379,580
7	Corporate Secretary	Gayle Littleton	696,280		2024-12-31
8	Corporate Secretary	Colette Honorable	618,000	2025-01-01

DIRECTORS
Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), name and abbreviated titles of the directors who are officers of the respondent. Provide the principle place of business in column (b), designate members of the Executive Committee in column (c), and the Chairman of the Executive Committee in column (d).
Line No.	NameAndTitleOfDirector Name (and Title) of Director (a)	PrincipalBusinessAddress Principal Business Address (b)	MemberOfTheExecutiveCommittee Member of the Executive Committee (c)	ChairmanOfTheExecutiveCommittee Chairman of the Executive Committee (d)
1	(a) Michael Innocenzo	2301 Market Street, Philadelphia, PA 19101	true	true
2	(b) Calvin G. Butler, Jr.	10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603	false	false
3	Gil Quiniones (Chief Executive Officer)	10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603	true	false
4	Ricardo Estrada	10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603	false	false
5	Zaldwaynaka Scott	10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603	false	false
6	Smita Shah	10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603	false	false
7	(c) Elizabeth Buchanan	10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603	false	false
8	(d) Stephen Bowman	10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603	false	false

INFORMATION ON FORMULA RATES
Does the respondent have formula rates?		☑ Yes ☐ No
Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate.
Line No.	RateScheduleTariffNumber FERC Rate Schedule or Tariff Number (a)	ProceedingDocketNumber FERC Proceeding (b)
1	Attachment H-13A of PJM of OATT	Docket No. ER07-583-000
2	Attachment H-13A of PJM of OATT - Revised	Docket No. ER10-1247-000
3	Attachment H-13A of PJM of OATT - Revised	Docket No. ER11-3577-000
4	Attachment H-13A of PJM of OATT - Revised	Docket No. ER12-1793-000
5	Attachment H-13A of PJM of OATT - Revised	Docket No. ER13-1391-000
6	Attachment H-13A of PJM of OATT - Revised	Docket No. ER14-1203-000
7	Attachment H-13A of PJM of OATT - Revised	Docket No. ER14-1708-000
8	Attachment H-13A of PJM of OATT - Revised	Docket No. ER14-1728-000
9	Attachment H-13A of PJM of OATT - Revised	Docket No. ER15-959-000
10	Attachment H-13A of PJM of OATT - Revised	Docket No. ER15-1515-000
11	Attachment H-13A of PJM of OATT - Revised	Docket No. ER17-863-000
12	Attachment H-13A of PJM of OATT - Revised	Docket No. ER 19-5-000
13	Attachment H-13A of PJM of OATT - Revised	Docket No. ER 19-876-000
14	Attachment H-13A of PJM of OATT - Revised	Docket No. ER 19-1478-000
15	Attachment H-13A of PJM of OATT - Revised	Docket No. ER 22-1082-000
16	Attachment H-13A of PJM of OATT - Revised	Docket No. ER 23-954-000

INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)?			☑ Yes ☐ No
If yes, provide a listing of such filings as contained on the Commission's eLibrary website.
Line No.	AccessionNumber Accession No. (a)	DocumentDate Document Date / Filed Date (b)	DocketNumber Docket No. (c)	DescriptionOfFiling Description (d)	RateScheduleTariffNumber Formula Rate FERC Rate Schedule Number or Tariff Number (e)
1	(a) 20080515-4024	05/15/2008	ER08-963-000	Formula Rate Annual Update	H-13 PJM OATT
2	20090601-0016	05/15/2009	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
3	20100514-5087	05/14/2010	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
4	20110516-5146	05/16/2011	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
5	20120515-5073	05/15/2012	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
6	20130429-5169	04/29/2013	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
7	20140416-5197	04/16/2014	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
8	20150415-5322	04/15/2015	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
9	20150519-5140	05/19/2015	ER09-1145-000	Formula Rate Annual Update - Correction	H-13 PJM OATT
10	20160413-5156	04/13/2016	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
11	20170413-5385	04/13/2017	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
12	20180504-5243	05/04/2018	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
13	20190510-5119	05/10/2019	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
14	20200515-5181	05/15/2020	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
15	20210416-5142	04/16/2021	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
16	20220429-5687	04/29/2022	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
17	20230512-5191	05/12/2023	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT
18	20240424-5311	04/24/2024	ER09-1145-000	Formula Rate Annual Update	H-13 PJM OATT

FERC FINANCIAL REPORT
FERC FORM No. 1: Annual Report of
Major Electric Utilities, Licensees
and Others and Supplemental
Form 3-Q: Quarterly Financial Report

INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

Purpose

Who Must Submit

What and Where to Submit

When to Submit

Where to Send Comments on Public Reporting Burden.

GENERAL INSTRUCTIONS

EXCERPTS FROM THE LAW

GENERAL PENALTIES




FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report

These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature

Schedules	Pages
Comparative Balance Sheet	110-113
Statement of Income	114-117
Statement of Retained Earnings	118-119
Statement of Cash Flows	120-121
Notes to Financial Statements	122-123

LIST OF SCHEDULES (Electric Utility)
Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".
Line No.	Title of Schedule (a)	Reference Page No. (b)	Remarks (c)
	ScheduleIdentificationAbstract Identification	1
	ScheduleListOfSchedulesAbstract List of Schedules	2
1	ScheduleGeneralInformationAbstract General Information	101
2	ScheduleControlOverRespondentAbstract Control Over Respondent	102
3	ScheduleCorporationsControlledByRespondentAbstract Corporations Controlled by Respondent	103
4	ScheduleOfficersAbstract Officers	104
5	ScheduleDirectorsAbstract Directors	105
6	ScheduleInformationOnFormulaRatesAbstract Information on Formula Rates	106
7	ScheduleImportantChangesDuringTheQuarterYearAbstract Important Changes During the Year	108
8	ScheduleComparativeBalanceSheetAbstract Comparative Balance Sheet	110
9	ScheduleStatementOfIncomeAbstract Statement of Income for the Year	114
10	ScheduleRetainedEarningsAbstract Statement of Retained Earnings for the Year	118
12	ScheduleStatementOfCashFlowsAbstract Statement of Cash Flows	120
12	ScheduleNotesToFinancialStatementsAbstract Notes to Financial Statements	122
13	ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract Statement of Accum Other Comp Income, Comp Income, and Hedging Activities	122a
14	ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep	200
15	ScheduleNuclearFuelMaterialsAbstract Nuclear Fuel Materials	202	N/A
16	ScheduleElectricPlantInServiceAbstract Electric Plant in Service	204
17	ScheduleElectricPropertyLeasedToOthersAbstract Electric Plant Leased to Others	213	N/A
18	ScheduleElectricPlantHeldForFutureUseAbstract Electric Plant Held for Future Use	214
19	ScheduleConstructionWorkInProgressElectricAbstract Construction Work in Progress-Electric	216
20	ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract Accumulated Provision for Depreciation of Electric Utility Plant	219
21	ScheduleInvestmentsInSubsidiaryCompaniesAbstract Investment of Subsidiary Companies	224
22	ScheduleMaterialsAndSuppliesAbstract Materials and Supplies	227
23	ScheduleAllowanceInventoryAbstract Allowances	228	N/A
24	ScheduleExtraordinaryPropertyLossesAbstract Extraordinary Property Losses	230a	N/A
25	ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract Unrecovered Plant and Regulatory Study Costs	230b	N/A
26	ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract Transmission Service and Generation Interconnection Study Costs	231
27	ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets	232
28	ScheduleMiscellaneousDeferredDebitsAbstract Miscellaneous Deferred Debits	233
29	ScheduleAccumulatedDeferredIncomeTaxesAbstract Accumulated Deferred Income Taxes	234
30	ScheduleCapitalStockAbstract Capital Stock	250
31	ScheduleOtherPaidInCapitalAbstract Other Paid-in Capital	253
32	ScheduleCapitalStockExpenseAbstract Capital Stock Expense	254b
33	ScheduleLongTermDebtAbstract Long-Term Debt	256
34	ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax	261
35	ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract Taxes Accrued, Prepaid and Charged During the Year	262
36	ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract Accumulated Deferred Investment Tax Credits	266
37	ScheduleOtherDeferredCreditsAbstract Other Deferred Credits	269
38	ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract Accumulated Deferred Income Taxes-Accelerated Amortization Property	272	N/A
39	ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract Accumulated Deferred Income Taxes-Other Property	274
40	ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract Accumulated Deferred Income Taxes-Other	276
41	ScheduleOtherRegulatoryLiabilitiesAbstract Other Regulatory Liabilities	278
42	ScheduleElectricOperatingRevenuesAbstract Electric Operating Revenues	300
43	ScheduleRegionalTransmissionServiceRevenuesAbstract Regional Transmission Service Revenues (Account 457.1)	302	N/A
44	ScheduleSalesOfElectricityByRateSchedulesAbstract Sales of Electricity by Rate Schedules	304
45	ScheduleSalesForResaleAbstract Sales for Resale	310
46	ScheduleElectricOperationsAndMaintenanceExpensesAbstract Electric Operation and Maintenance Expenses	320
47	SchedulePurchasedPowerAbstract Purchased Power	326
48	ScheduleTransmissionOfElectricityForOthersAbstract Transmission of Electricity for Others	328
49	ScheduleTransmissionOfElectricityByIsoOrRtoAbstract Transmission of Electricity by ISO/RTOs	331	N/A
50	ScheduleTransmissionOfElectricityByOthersAbstract Transmission of Electricity by Others	332
51	ScheduleMiscellaneousGeneralExpensesAbstract Miscellaneous General Expenses-Electric	335
52	ScheduleDepreciationDepletionAndAmortizationAbstract Depreciation and Amortization of Electric Plant (Account 403, 404, 405)	336
53	ScheduleRegulatoryCommissionExpensesAbstract Regulatory Commission Expenses	350
54	ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract Research, Development and Demonstration Activities	352
55	ScheduleDistributionOfSalariesAndWagesAbstract Distribution of Salaries and Wages	354
56	ScheduleCommonUtilityPlantAndExpensesAbstract Common Utility Plant and Expenses	356	N/A
57	ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract Amounts included in ISO/RTO Settlement Statements	397
58	SchedulePurchasesSalesOfAncillaryServicesAbstract Purchase and Sale of Ancillary Services	398
59	ScheduleMonthlyTransmissionSystemPeakLoadAbstract Monthly Transmission System Peak Load	400
60	ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract Monthly ISO/RTO Transmission System Peak Load	400a	N/A
61	ScheduleElectricEnergyAccountAbstract Electric Energy Account	401a
62	ScheduleMonthlyPeakAndOutputAbstract Monthly Peaks and Output	401b
63	ScheduleSteamElectricGeneratingPlantStatisticsAbstract Steam Electric Generating Plant Statistics	402	N/A
64	ScheduleHydroelectricGeneratingPlantStatisticsAbstract Hydroelectric Generating Plant Statistics	406	N/A
65	SchedulePumpedStorageGeneratingPlantStatisticsAbstract Pumped Storage Generating Plant Statistics	408	N/A
66	ScheduleGeneratingPlantStatisticsAbstract Generating Plant Statistics Pages	410	N/A
66.1	ScheduleEnergyStorageOperationsLargePlantsAbstract Energy Storage Operations (Large Plants)	414	N/A
66.2	ScheduleEnergyStorageOperationsSmallPlantsAbstract Energy Storage Operations (Small Plants)	419	N/A
67	ScheduleTransmissionLineStatisticsAbstract Transmission Line Statistics Pages	422
68	ScheduleTransmissionLinesAddedAbstract Transmission Lines Added During Year	424	N/A
69	ScheduleSubstationsAbstract Substations	426
70	ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract Transactions with Associated (Affiliated) Companies	429
71	FootnoteDataAbstract Footnote Data	450
	StockholdersReportsAbstract Stockholders' Reports (check appropriate box)
	Stockholders' Reports Check appropriate box: ☐ Two copies will be submitted ☐ No annual report to stockholders is prepared

CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.

Exelon Corporation (Exelon) indirectly owns 99.99% of ComEd's common stock through Exelon's consolidated subsidiary Exelon Energy Delivery, LLC.

CORPORATIONS CONTROLLED BY RESPONDENT
Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests. Definitions See the Uniform System of Accounts for a definition of control. Direct control is that which is exercised without interposition of an intermediary. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party.
Line No.	NameOfCompanyControlledByRespondent Name of Company Controlled (a)	CompanyControlledByRespondentKindOfBusinessDescription Kind of Business (b)	VotingStockOwnedByRespondentPercentage Percent Voting Stock Owned (c)	FootnoteReferences Footnote Ref. (d)
1	Commonwealth Edison Company of Indiana, Inc.	Transmission of electricity	100
2	ComEd Financing III	Financing Trust	100
3	RITELine Illinois, LLC	Transmission of electricity	75
4	EdiSun, LLC	Development of solar panels	100

INFORMATION ON FORMULA RATES - Formula Rate Variances
If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from amounts reported in the Form 1. The footnote should provide a narrative description explaining how the "rate" (or billing) was derived if different from the reported amount in the Form 1. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote.
Line No.	PageNumberOfFormulaRateVariances Page No(s). (a)	ScheduleOfFormulaRateVariances Schedule (b)	ColumnOfFormulaRateVariances Column (c)	LineNumberOfFormulaRateVariances Line No. (d)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44

IMPORTANT CHANGES DURING THE QUARTER/YEAR
Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments. State the estimated annual effect and nature of any important wage scale changes during the year. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Pages 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest. (Reserved.) If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.

1. None.
2. None.
3. None.
4. None.
5. None.
6. Refer to Pages 122-123, Notes to Financial Statements: Note 10 — Debt and Credit Agreements for additional information on ComEd’s Debt and Credit activity in 2024 and back schedule pages 256-257 for discussion of ComEd’s long-term debt. ComEd issues long-term debt under Orders by the Illinois Commerce Commission (ICC) approving ComEd’s securities. As of December 31, 2024, ComEd has New Money authority outstanding under Order 23-0492 totaling $1.8 billion and under Refinancing authority outstanding under Order 24-0104 totaling $500 million. On December 14, 2023, the ICC approved ComEd's request for $2.0 billion of New Money Authority, with an effective date of January 1, 2024, which will expire January 1, 2027. On February 20, 2024 ComEd Filed an application for $750 million in refinancing authority under Order 24-0104 from the ICC, which was approved on April 18, 2024. The refinancing authority under the approved application has an effective date of May 1, 2024, and extends the expiration date to May 1, 2027. ComEd's commercial paper borrowings are issued under the authority of FERC order Docket No. ES24-4-000 for up to $2.5 billion of short-term debt over the course of two years. ComEd's short-term financing authority expires on December 31, 2025. As of December 31, 2023, ComEd had an effective shelf registration statement unlimited in amount, filed with the SEC, that is set to expire on August 3, 2025. As of February 21, 2024, Exelon Corporation filed with the SEC a post-effective amendment to its shelf registration statement. As a result of the post-effective amendment, Exelon Corporation amended the existing shelf and is authorized to issue $7,200 million in securities. ComEd is listed as a co-registrant on the post-effective amendment filed with the SEC on February 21, 2024, and has the ability to issue a portion of the authorized Exelon Corporation amount in debt securities. There were no changes made to the August 3, 2025 expiration date of the shelf registration statement as a result of the post-effective amendment. ComEd’s ability to sell securities off the shelf registration statement or to access the private placement markets will depend on a number of factors at the time of the proposed sale, including other required regulatory approvals, as applicable, ComEd’s current financial condition, its securities ratings and market conditions.
7. None.
8. A base pay increase pool of 3% was distributed among exempt and non-exempt, non-represented employees on March 1, 2024 and 2025.
9. Refer to Pages 122-123, Notes to Financial Statements: Note 2 — Regulatory Matters and Note 12 - Commitments and Contingencies “Litigation and Regulatory Matters” section.
10. None.
12. None.
See Officers page (Page 104) and Directors page (Page 105) for details concerning changes in the respondent's officers and directors.
14. None.

COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlant Utility Plant (101-106, 114)	200	41,967,470,622	40,315,002,584
3	ConstructionWorkInProgress Construction Work in Progress (107)	200	1,220,404,574	1,395,544,738
4	UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3)		43,187,875,196	41,710,547,322
5	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)	200	12,206,668,092	11,713,097,084
6	UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5)		30,981,207,104	29,997,450,238
7	NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)	202
8	NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly Nuclear Fuel Materials and Assemblies-Stock Account (120.2)
9	NuclearFuelAssembliesInReactorMajorOnly Nuclear Fuel Assemblies in Reactor (120.3)
10	SpentNuclearFuelMajorOnly Spent Nuclear Fuel (120.4)
11	NuclearFuelUnderCapitalLeases Nuclear Fuel Under Capital Leases (120.6)
12	AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)	202
13	NuclearFuelNet Net Nuclear Fuel (Enter Total of lines 7-11 less 12)
14	UtilityPlantAndNuclearFuelNet Net Utility Plant (Enter Total of lines 6 and 13)		30,981,207,104	29,997,450,238
15	OtherElectricPlantAdjustments Utility Plant Adjustments (116)
16	GasStoredUndergroundNoncurrent Gas Stored Underground - Noncurrent (117)
17	OtherPropertyAndInvestmentsAbstract OTHER PROPERTY AND INVESTMENTS
18	NonutilityProperty Nonutility Property (121)		9,697,258	9,697,258
19	AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122)		1,935,976	1,905,868
20	InvestmentInAssociatedCompanies Investments in Associated Companies (123)
21	InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1)	224	106,206,800	102,288,128
23	NoncurrentPortionOfAllowances Noncurrent Portion of Allowances	228
24	OtherInvestments Other Investments (124)		43,427	37,334
25	SinkingFunds Sinking Funds (125)
26	DepreciationFund Depreciation Fund (126)
27	AmortizationFundFederal Amortization Fund - Federal (127)
28	OtherSpecialFunds Other Special Funds (128)
29	SpecialFunds Special Funds (Non Major Only) (129)
30	DerivativeInstrumentAssetsLongTerm Long-Term Portion of Derivative Assets (175)
31	DerivativeInstrumentAssetsHedgesLongTerm Long-Term Portion of Derivative Assets - Hedges (176)
32	OtherPropertyAndInvestments TOTAL Other Property and Investments (Lines 18-21 and 23-31)		114,011,509	110,116,852
33	CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS
34	CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130)
35	Cash Cash (131)		17,224,016	45,643,539
36	SpecialDeposits Special Deposits (132-134)		485,877,839	401,566,878
37	WorkingFunds Working Fund (135)
38	TemporaryCashInvestments Temporary Cash Investments (136)		39,423,613	23,989,634
39	NotesReceivable Notes Receivable (141)
40	CustomerAccountsReceivable Customer Accounts Receivable (142)		659,142,561	508,571,219
41	OtherAccountsReceivable Other Accounts Receivable (143)		281,592,347	242,277,627
42	AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144)		143,245,638	86,250,851
43	NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145)
44	AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146)		528,228	70,491
45	FuelStock Fuel Stock (151)	227
46	FuelStockExpensesUndistributed Fuel Stock Expenses Undistributed (152)	227
47	Residuals Residuals (Elec) and Extracted Products (153)	227
48	PlantMaterialsAndOperatingSupplies Plant Materials and Operating Supplies (154)	227	297,689,734	285,561,287
49	Merchandise Merchandise (155)	227
50	OtherMaterialsAndSupplies Other Materials and Supplies (156)	227
51	NuclearMaterialsHeldForSale Nuclear Materials Held for Sale (157)	202/227
52	AllowanceInventoryAndWithheld Allowances (158.1 and 158.2)	228
53	NoncurrentPortionOfAllowances (Less) Noncurrent Portion of Allowances	228
54	StoresExpenseUndistributed Stores Expense Undistributed (163)	227
55	GasStoredCurrent Gas Stored Underground - Current (164.1)
56	LiquefiedNaturalGasStoredAndHeldForProcessing Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57	Prepayments Prepayments (165)		115,572,656	102,590,569
58	AdvancesForGas Advances for Gas (166-167)
59	InterestAndDividendsReceivable Interest and Dividends Receivable (171)		12,699	10,540
60	RentsReceivable Rents Receivable (172)
61	AccruedUtilityRevenues Accrued Utility Revenues (173)		334,534,395	351,134,876
62	MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174)		4,020,994	4,318,888
63	DerivativeInstrumentAssets Derivative Instrument Assets (175)
64	DerivativeInstrumentAssetsLongTerm (Less) Long-Term Portion of Derivative Instrument Assets (175)
65	DerivativeInstrumentAssetsHedges Derivative Instrument Assets - Hedges (176)
66	DerivativeInstrumentAssetsHedgesLongTerm (Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67	CurrentAndAccruedAssets Total Current and Accrued Assets (Lines 34 through 66)		2,092,373,444	1,879,484,697
68	DeferredDebitsAbstract DEFERRED DEBITS
69	UnamortizedDebtExpense Unamortized Debt Expenses (181)		103,067,099	99,782,409
70	ExtraordinaryPropertyLosses Extraordinary Property Losses (182.1)	230a
71	UnrecoveredPlantAndRegulatoryStudyCosts Unrecovered Plant and Regulatory Study Costs (182.2)	230b
72	OtherRegulatoryAssets Other Regulatory Assets (182.3)	232	3,996,746,550	4,396,564,225
73	PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183)
74	PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges Preliminary Natural Gas Survey and Investigation Charges 183.1)
75	OtherPreliminarySurveyAndInvestigationCharges Other Preliminary Survey and Investigation Charges (183.2)
76	ClearingAccounts Clearing Accounts (184)		56	325
77	TemporaryFacilities Temporary Facilities (185)
78	MiscellaneousDeferredDebits Miscellaneous Deferred Debits (186)	233	5,977,542,374	4,997,467,960
79	DeferredLossesFromDispositionOfUtilityPlant Def. Losses from Disposition of Utility Plt. (187)
80	ResearchDevelopmentAndDemonstrationExpenditures Research, Devel. and Demonstration Expend. (188)	352
81	UnamortizedLossOnReacquiredDebt Unamortized Loss on Reaquired Debt (189)		14,839,627	16,424,002
82	AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190)	234	871,112,133	1,006,863,343
83	UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191)
84	DeferredDebits Total Deferred Debits (lines 69 through 83)		10,963,307,727	10,517,102,264
85	AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84)		44,150,899,784	42,504,154,051

COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	ProprietaryCapitalAbstract PROPRIETARY CAPITAL
2	CommonStockIssued Common Stock Issued (201)	250	1,587,297,245	1,587,297,032
3	PreferredStockIssued Preferred Stock Issued (204)	250
4	CapitalStockSubscribed Capital Stock Subscribed (202, 205)
5	StockLiabilityForConversion Stock Liability for Conversion (203, 206)
6	PremiumOnCapitalStock Premium on Capital Stock (207)		5,020,105,353	5,020,104,944
7	OtherPaidInCapital Other Paid-In Capital (208-211)	253	5,615,312,040	5,388,756,067
8	InstallmentsReceivedOnCapitalStock Installments Received on Capital Stock (212)	252
9	DiscountOnCapitalStock (Less) Discount on Capital Stock (213)	254
10	CapitalStockExpense (Less) Capital Stock Expense (214)	254b	6,942,925	6,942,925
11	RetainedEarnings Retained Earnings (215, 215.1, 216)	118	2,608,976,284	2,327,289,291
12	UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1)	118	60,499,848	51,743,312
13	ReacquiredCapitalStock (Less) Reacquired Capital Stock (217)	250
14	NoncorporateProprietorship Noncorporate Proprietorship (Non-major only) (218)
15	AccumulatedOtherComprehensiveIncome Accumulated Other Comprehensive Income (219)	122(a)(b)
16	ProprietaryCapital Total Proprietary Capital (lines 2 through 15)		14,885,247,845	14,368,247,721
17	LongTermDebtAbstract LONG-TERM DEBT
18	Bonds Bonds (221)	256	12,153,600,000	11,603,600,000
19	ReacquiredBonds (Less) Reacquired Bonds (222)	256
20	AdvancesFromAssociatedCompanies Advances from Associated Companies (223)	256	206,186,000	206,186,000
21	OtherLongTermDebt Other Long-Term Debt (224)	256
22	UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225)
23	UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226)		30,683,580	28,371,972
24	LongTermDebt Total Long-Term Debt (lines 18 through 23)		12,329,102,420	11,781,414,028
25	OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES
26	ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227)		7,475,353	7,532,029
27	AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1)
28	AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2)		120,642,632	81,424,515
29	AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3)		191,071,720	197,131,365
30	AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4)		284,584,833	302,552,734
31	AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229)		8,484,459	7,188,191
32	LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities
33	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges
34	AssetRetirementObligations Asset Retirement Obligations (230)		169,137,189	151,156,355
35	OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34)		781,396,186	746,985,189
36	CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES
37	NotesPayable Notes Payable (231)		35,995,450	601,937,997
38	AccountsPayable Accounts Payable (232)		713,392,804	828,813,132
39	NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233)
40	AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234)		77,043,053	72,879,463
41	CustomerDeposits Customer Deposits (235)		134,362,405	118,238,326
42	TaxesAccrued Taxes Accrued (236)	262	95,223,579	211,291,922
43	InterestAccrued Interest Accrued (237)		151,720,942	149,033,092
44	DividendsDeclared Dividends Declared (238)
45	MaturedLongTermDebt Matured Long-Term Debt (239)
46	MaturedInterest Matured Interest (240)
47	TaxCollectionsPayable Tax Collections Payable (241)		28,435,908	31,397,970
48	MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242)		504,717,529	440,174,247
49	ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243)		76,276	70,210
50	DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244)
51	LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities
52	DerivativeInstrumentLiabilitiesHedges Derivative Instrument Liabilities - Hedges (245)
53	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges (Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54	CurrentAndAccruedLiabilities Total Current and Accrued Liabilities (lines 37 through 53)		1,740,967,946	2,453,836,359
55	DeferredCreditsAbstract DEFERRED CREDITS
56	CustomerAdvancesForConstruction Customer Advances for Construction (252)		781,908,871	455,558,952
57	AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255)	266	6,278,126	6,810,301
58	DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256)
59	OtherDeferredCredits Other Deferred Credits (253)	269	116,180,770	120,260,137
60	OtherRegulatoryLiabilities Other Regulatory Liabilities (254)	278	7,052,743,824	6,253,543,172
61	UnamortizedGainOnReacquiredDebt Unamortized Gain on Reacquired Debt (257)
62	AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty Accum. Deferred Income Taxes-Accel. Amort.(281)	272
63	AccumulatedDeferredIncomeTaxesOtherProperty Accum. Deferred Income Taxes-Other Property (282)		5,041,294,728	4,971,124,063
64	AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283)		(a) 1,415,779,068	1,346,374,129
65	DeferredCredits Total Deferred Credits (lines 56 through 64)		14,414,185,387	13,153,670,754
66	LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)		44,150,899,784	42,504,154,051

STATEMENT OF INCOME
Quarterly Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter. If additional columns are needed, place them in a footnote. Annual or Quarterly if applicable Do not report fourth quarter data in columns (e) and (f) Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above. Use page 122 for important notes regarding the statement of income for any account thereof. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.	Title of Account (a)	(Ref.) Page No. (b)	Total Current Year to Date Balance for Quarter/Year (c)	Total Prior Year to Date Balance for Quarter/Year (d)	Current 3 Months Ended - Quarterly Only - No 4th Quarter (e)	Prior 3 Months Ended - Quarterly Only - No 4th Quarter (f)	Electric Utility Current Year to Date (in dollars) (g)	Electric Utility Previous Year to Date (in dollars) (h)	Gas Utiity Current Year to Date (in dollars) (i)	Gas Utility Previous Year to Date (in dollars) (j)	Other Utility Current Year to Date (in dollars) (k)	Other Utility Previous Year to Date (in dollars) (l)
1	UtilityOperatingIncomeAbstract UTILITY OPERATING INCOME
2	OperatingRevenues Operating Revenues (400)	300	8,163,984,950	7,847,450,785			8,163,984,950	7,847,450,785
3	OperatingExpensesAbstract Operating Expenses
4	OperationExpense Operation Expenses (401)	320	4,234,423,204	3,832,950,659			4,234,423,204	3,832,950,659
5	MaintenanceExpense Maintenance Expenses (402)	320	492,900,321	459,380,558			492,900,321	459,380,558
6	DepreciationExpense Depreciation Expense (403)	336	1,052,277,392	1,006,052,806			1,052,277,392	1,006,052,806
7	DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1)	336	1,830,160	1,858,923			1,830,160	1,858,923
8	AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405)	336	129,435,286	100,660,161			129,435,286	100,660,161
9	AmortizationOfElectricPlantAcquisitionAdjustments Amort. of Utility Plant Acq. Adj. (406)	336
10	AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)
11	AmortizationOfConversionExpenses Amort. of Conversion Expenses (407.2)
12	RegulatoryDebits Regulatory Debits (407.3)		346,966,972	305,964,625			346,966,972	305,964,625
13	RegulatoryCredits (Less) Regulatory Credits (407.4)		(a) 118,650,816	(b) 62,177,236			118,650,816	62,177,236
14	TaxesOtherThanIncomeTaxesUtilityOperatingIncome Taxes Other Than Income Taxes (408.1)	262	372,144,480	367,534,329			372,144,480	367,534,329
15	IncomeTaxesOperatingIncome Income Taxes - Federal (409.1)	262	70,955,520	129,557,732			70,955,520	129,557,732
16	IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1)	262	61,713,309	11,432,424			61,713,309	11,432,424
17	ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1)	234, 272	463,852,957	592,520,153			463,852,957	592,520,153
18	ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1)	234, 272	488,297,479	399,639,434			488,297,479	399,639,434
19	InvestmentTaxCreditAdjustments Investment Tax Credit Adj. - Net (411.4)	266	993,294	1,218,203			993,294	1,218,203
20	GainsFromDispositionOfPlant (Less) Gains from Disp. of Utility Plant (411.6)
21	LossesFromDispositionOfServiceCompanyPlant Losses from Disp. of Utility Plant (411.7)
22	GainsFromDispositionOfAllowances (Less) Gains from Disposition of Allowances (411.8)
23	LossesFromDispositionOfAllowances Losses from Disposition of Allowances (411.9)
24	AccretionExpense Accretion Expense (411.10)		30,043	51,297			30,043	51,297
25	UtilityOperatingExpenses TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)		6,618,588,055	6,322,063,946			6,618,588,055	6,322,063,946
27	NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25)		1,545,396,895	1,525,386,839			1,545,396,895	1,525,386,839
28	OtherIncomeAndDeductionsAbstract Other Income and Deductions
29	OtherIncomeAbstract Other Income
30	NonutilityOperatingIncomeAbstract Nonutilty Operating Income
31	RevenuesFromMerchandisingJobbingAndContractWork Revenues From Merchandising, Jobbing and Contract Work (415)		77,031,423	22,794,716
32	CostsAndExpensesOfMerchandisingJobbingAndContractWork (Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)		77,606,927	22,319,615
33	RevenuesFromNonutilityOperations Revenues From Nonutility Operations (417)
34	ExpensesOfNonutilityOperations (Less) Expenses of Nonutility Operations (417.1)
35	NonoperatingRentalIncome Nonoperating Rental Income (418)
36	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1)	119	9,149,347	5,517,419
37	InterestAndDividendIncome Interest and Dividend Income (419)		23,310,870	22,029,291
38	AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1)		46,146,117	33,462,076
39	MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421)		23,253,461	17,817,710
40	GainOnDispositionOfProperty Gain on Disposition of Property (421.1)
41	OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40)		101,284,291	79,301,597
42	OtherIncomeDeductionsAbstract Other Income Deductions
43	LossOnDispositionOfProperty Loss on Disposition of Property (421.2)
44	MiscellaneousAmortization Miscellaneous Amortization (425)
45	Donations Donations (426.1)		5,175,524	5,905,354
46	LifeInsurance Life Insurance (426.2)		25,408	8,098
47	Penalties Penalties (426.3)		621,319	1,168,760
48	ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4)		3,978,809	5,200,212
49	OtherDeductions Other Deductions (426.5)		63,209,847	16,614,085
50	OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49)		71,768,269	28,880,313
51	TaxesApplicableToOtherIncomeAndDeductionsAbstract Taxes Applic. to Other Income and Deductions
52	TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions Taxes Other Than Income Taxes (408.2)	262	2,503,180	956,149
53	IncomeTaxesFederal Income Taxes-Federal (409.2)	262	2,979,344	6,753,836
54	IncomeTaxesOther Income Taxes-Other (409.2)	262	2,385,084	1,295,297
55	ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2)	234, 272	5,403,183
56	ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions (Less) Provision for Deferred Income Taxes-Cr. (411.2)	234, 272		4,162,560
57	InvestmentTaxCreditAdjustmentsNonutilityOperations Investment Tax Credit Adj.-Net (411.5)
58	InvestmentTaxCredits (Less) Investment Tax Credits (420)
59	TaxesOnOtherIncomeAndDeductions TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)		8,500,623	4,842,722
60	NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59)		21,015,399	45,578,562
61	InterestChargesAbstract Interest Charges
62	InterestOnLongTermDebt Interest on Long-Term Debt (427)		483,054,341	457,291,632
63	AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428)		7,724,318	7,063,111
64	AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1)		1,584,375	1,584,375
65	AmortizationOfPremiumOnDebtCredit (Less) Amort. of Premium on Debt-Credit (429)
66	AmortizationOfGainOnReacquiredDebtCredit (Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67	InterestOnDebtToAssociatedCompanies Interest on Debt to Assoc. Companies (430)		13,092,811	13,092,811
68	OtherInterestExpense Other Interest Expense (431)		23,810,563	36,332,711
69	AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)		28,941,211	38,477,582
70	NetInterestCharges Net Interest Charges (Total of lines 62 thru 69)		500,325,197	476,887,058
71	IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70)		1,066,087,097	1,094,078,343
72	ExtraordinaryItemsAbstract Extraordinary Items
73	ExtraordinaryIncome Extraordinary Income (434)
74	ExtraordinaryDeductions (Less) Extraordinary Deductions (435)
75	NetExtraordinaryItems Net Extraordinary Items (Total of line 73 less line 74)
76	IncomeTaxesExtraordinaryItems Income Taxes-Federal and Other (409.3)	262
77	ExtraordinaryItemsAfterTaxes Extraordinary Items After Taxes (line 75 less line 76)
78	NetIncomeLoss Net Income (Total of line 71 and 77)		1,066,087,097	1,094,078,343

STATEMENT OF RETAINED EARNINGS
Do not report Lines 49-53 on the quarterly report. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b). State the purpose and amount for each reservation or appropriation of retained earnings. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order. Show dividends for each class and series of capital stock. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No.	Item (a)	Contra Primary Account Affected (b)	Current Quarter/Year Year to Date Balance (c)	Previous Quarter/Year Year to Date Balance (d)
	UnappropriatedRetainedEarningsAbstract UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1	UnappropriatedRetainedEarnings Balance-Beginning of Period		1,689,302,284	1,684,177,676
2	ChangesAbstract Changes
3	AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439)
4	AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit
9	AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439)
10	AdjustmentsToRetainedEarningsDebitAbstract Adjustments to Retained Earnings Debit
15	AdjustmentsToRetainedEarningsDebit TOTAL Debits to Retained Earnings (Acct. 439)
16	BalanceTransferredFromIncome Balance Transferred from Income (Account 433 less Account 418.1)		1,056,937,750	1,088,560,924
17	AppropriationsOfRetainedEarningsAbstract Appropriations of Retained Earnings (Acct. 436)
17.1	AppropriationsOfRetainedEarnings Transfer to appropriated retained earnings for payment of future dividends		1,066,087,097	1,094,078,343
22	AppropriationsOfRetainedEarnings TOTAL Appropriations of Retained Earnings (Acct. 436)		1,066,087,097	1,094,078,343
23	DividendsDeclaredPreferredStockAbstract Dividends Declared-Preferred Stock (Account 437)
29	DividendsDeclaredPreferredStock TOTAL Dividends Declared-Preferred Stock (Acct. 437)
30	DividendsDeclaredCommonStockAbstract Dividends Declared-Common Stock (Account 438)
36	DividendsDeclaredCommonStock TOTAL Dividends Declared-Common Stock (Acct. 438)
37	TransfersFromUnappropriatedUndistributedSubsidiaryEarnings Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings		392,811	392,811
38	UnappropriatedRetainedEarnings Balance - End of Period (Total 1,9,15,16,22,29,36,37)		1,698,058,820	1,689,302,284
39	AppropriatedRetainedEarningsAbstract APPROPRIATED RETAINED EARNINGS (Account 215)
39.1	AppropriatedRetainedEarnings Balance - Beginning of Year (Debit or Credit)		4,016,591,575	3,667,874,778
39.2	AppropriatedRetainedEarnings Appropriations of retained earnings for future dividend payments		1,066,087,097	1,094,078,343
39.3	AppropriatedRetainedEarnings Dividends declared		775,643,568	745,361,546
39.4	AppropriatedRetainedEarnings Tax Adjustment for FIN48
45	AppropriatedRetainedEarnings TOTAL Appropriated Retained Earnings (Account 215)		4,307,035,104	4,016,591,575
	AppropriatedRetainedEarningsAmortizationReserveFederalAbstract APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46	AppropriatedRetainedEarningsAmortizationReserveFederal TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)
47	AppropriatedRetainedEarningsIncludingReserveAmortization TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)		4,307,035,104	4,016,591,575
48	RetainedEarnings TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)		2,608,976,284	2,327,289,291
	UnappropriatedUndistributedSubsidiaryEarningsAbstract UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49	UnappropriatedUndistributedSubsidiaryEarnings Balance-Beginning of Year (Debit or Credit)		51,743,312	46,618,704
50	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings for Year (Credit) (Account 418.1)		9,149,347	5,517,419
51	DividendsReceived (Less) Dividends Received (Debit)		392,811	392,811
52	ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
53	UnappropriatedUndistributedSubsidiaryEarnings Balance-End of Year (Total lines 49 thru 52)		60,499,848	51,743,312

STATEMENT OF CASH FLOWS
Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.	Description (See Instructions No.1 for explanation of codes) (a)	Current Year to Date Quarter/Year (b)	Previous Year to Date Quarter/Year (c)
1	NetCashFlowFromOperatingActivitiesAbstract Net Cash Flow from Operating Activities
2	NetIncomeLoss Net Income (Line 78(c) on page 117)	1,066,087,097	1,094,078,343
3	NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income:
4	DepreciationAndDepletion Depreciation and Depletion	1,183,542,838	1,106,846,515
5	NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details)
5.1	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Amortization of Regulatory Debits	346,966,972	307,690,000
8	DeferredIncomeTaxesNet Deferred Income Taxes (Net)	19,041,339	188,718,159
9	InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net)	993,294	1,218,203
10	NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables	164,328,725	91,686,824
11	NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory	12,128,447	82,594,953
12	NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory
13	NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses	210,496,077	149,791,921
14	NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets	109,980,587	1,203,735,116
15	NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities	283,556,370	566,474,926
16	AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction	46,146,117	33,462,076
17	UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies	9,149,347	5,517,419
18	OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote):
18.1	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other (provide details in footnote):	(a) 240,243,317	(c) 263,962,518
22	NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)	2,768,093,835	1,731,422,755
24	CashFlowsFromInvestmentActivitiesAbstract Cash Flows from Investment Activities:
25	ConstructionAndAcquisitionOfPlantIncludingLandAbstract Construction and Acquisition of Plant (including land):
26	GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities Gross Additions to Utility Plant (less nuclear fuel)	2,258,686,786	2,634,454,072
27	GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel
28	GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant
29	GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant
30	AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction	46,146,117	33,462,076
31	OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote):
31.1	OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription Other (provide details in footnote):
34	CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33)	2,212,540,669	2,600,991,996
36	AcquisitionOfOtherNoncurrentAssets Acquisition of Other Noncurrent Assets (d)
37	ProceedsFromDisposalOfNoncurrentAssets Proceeds from Disposal of Noncurrent Assets (d)	4,243,166	9,756,179
39	InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Investments in and Advances to Assoc. and Subsidiary Companies	162,136	356,735
40	ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies Contributions and Advances from Assoc. and Subsidiary Companies	5,392,811	392,811
41	DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract Disposition of Investments in (and Advances to)
42	DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
44	PurchaseOfInvestmentSecurities Purchase of Investment Securities (a)
45	ProceedsFromSalesOfInvestmentSecurities Proceeds from Sales of Investment Securities (a)
46	LoansMadeOrPurchased Loans Made or Purchased
47	CollectionsOnLoans Collections on Loans
49	NetIncreaseDecreaseInReceivablesInvestingActivities Net (Increase) Decrease in Receivables
50	NetIncreaseDecreaseInInventoryInvestingActivities Net (Increase) Decrease in Inventory
51	NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities Net (Increase) Decrease in Allowances Held for Speculation
52	NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities Net Increase (Decrease) in Payables and Accrued Expenses
53	OtherAdjustmentsToCashFlowsFromInvestmentActivities Other (provide details in footnote):
53.1	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Other (provide details in footnote):	(b) 235,976	(d) 1,665,388
57	CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)	2,202,830,852	2,592,865,129
59	CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities:
60	ProceedsFromIssuanceAbstract Proceeds from Issuance of:
61	ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b)	800,000,000	975,000,000
62	ProceedsFromIssuanceOfPreferredStockFinancingActivities Preferred Stock
63	ProceedsFromIssuanceOfCommonStockFinancingActivities Common Stock	622	211
64	OtherAdjustmentsToCashFlowsFromFinancingActivities Other (provide details in footnote):
64.1	OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription Other: Contributions from Parent	226,556,660	655,545,330
66	NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c)		25,083,697
67	OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote):
67.1	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote):
67.2	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Debt Issuance Costs	13,219,007	13,830,728
70	CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69)	1,013,338,275	1,641,798,510
72	PaymentsForRetirementAbstract Payments for Retirement of:
73	PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b)	250,000,000
74	PaymentsForRetirementOfPreferredStockFinancingActivities Preferred Stock
75	PaymentsForRetirementOfCommonStockFinancingActivities Common Stock	687	253
76	OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities Other (provide details in footnote):
76.1	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Other (provide details in footnote):
76.2	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Bond Issuance Costs
78	NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c)	565,942,547
80	DividendsOnPreferredStock Dividends on Preferred Stock
81	DividendsOnCommonStock Dividends on Common Stock	775,643,568	745,361,546
83	CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)	578,248,527	896,436,711
85	NetIncreaseDecreaseInCashAndCashEquivalentsAbstract Net Increase (Decrease) in Cash and Cash Equivalents
86	NetIncreaseDecreaseInCashAndCashEquivalents Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83)	12,985,544	34,994,337
88	CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period	69,633,173	34,638,836
90	CashAndCashEquivalents Cash and Cash Equivalents at End of Period	56,647,629	69,633,173

TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
Report below the information called for concerning all non-power goods or services received from or provided to associated (affiliated) companies. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount billed to the respondent or billed to an associated/affiliated company for non-power goods and services. The good or service must be specific in nature. Respondents should not attempt to include or aggregate amounts in a nonspecific category such as "general". Where amounts billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote.
Line No.	Description of the Good or Service (a)	Name of Associated/Affiliated Company (b)	Account(s) Charged or Credited (c)	Amount Charged or Credited (d)
1	Non-power Goods or Services Provided by Affiliated
2	Information Technology	Baltimore Gas & Electric	107, 456, 920, 923	648,560
3	Other	Baltimore Gas & Electric	146	21,765
4	Information Technology	Pepco Holdings LLC	107, 108, 923	209,858
5	Materials	Pepco Holdings LLC	517, 154	2,747
6	Transmission Services	ComEd of Indiana	565	5,271,201
7	Materials	PECO Energy Company	146	613,569
8	Information Technology	PECO Energy Company	920, 107	165,344
9	Financial Services - Direct	(a) Exelon BSC	923	5,165,029
10	Communications Services - Direct	Exelon BSC	923	321,029
11	Human Resources - Direct	Exelon BSC	107, 108, 923, 925	22,685,092
12	Legal Governance - Direct	Exelon BSC	426, 923	2,822,568
13	Executive Services - Direct	Exelon BSC	920	69,062
14	Utility Services - Direct	Exelon BSC	560, 923	1,442,251
15	Real Estate Services - Direct	Exelon BSC	923, 108. 107	131,809
16	Supply Services - Direct	Exelon BSC	107, 108, 163, 182, 920, 923	190,603
17	Information Technology - Direct	Exelon BSC	(b) Various	117,742,571
18	Legal Services - Direct	Exelon BSC	426	1,131,606
19	Financial Services - Indirect	Exelon BSC	107, 108, 923, 930	46,996,479
20	Communications Services - Indirect	Exelon BSC	426, 923	8,333,204
21	Human Resources - Indirect	Exelon BSC	920, 923, 930	2,235,103
22	Legal Governance - Indirect	Exelon BSC	107, 108, 426, 923, 930	19,065,213
23	Executive Services - Indirect	Exelon BSC	923	24,559,915
24	Operations Services - Indirect	Exelon BSC	920, 923	792,906
25	Real Estate Services - Indirect	Exelon BSC	923, 930, 935	3,315,447
26	Security Services - Indirect	Exelon BSC	107, 566, 923, 930	11,476,584
27	Utilities Services - Indirect	Exelon BSC	107, 560, 566, 588, 903, 923	34,941,206
28	Supply Services - Indirect	Exelon BSC	107, 108, 163, 920, 920, 923, 930	15,340,441
29	Information Technology - Indirect	Exelon BSC	(c) Various	330,289,342
30	Regulatory Governmental Affairs - Indirect	Exelon BSC	923	3,248,520
31	BSC Other - Indirect	Exelon BSC	920, 923	24,648,881
19
20	Non-power Goods or Services Provided for Affiliated
21	Real Estate & Facilities	Exelon BSC	454, 456, 186	7,062,259
22	Fleet Maintenance	Exelon BSC	920, 184	2,962
23	Other	Exelon BSC	107, 146, 923, 920, 426, 930, 935	967,290
24	Construction, O&M & Admin Fees	ComEd of Indiana	107, 108	792,254
25	Information Technology	Baltimore Gas & Electric	186, 107, 456, 923	25,585
26	Legal Department Services	Baltimore Gas & Electric	146	53,403
27	Audit Services	Baltimore Gas & Electric	146	724
28	Transmission Services	Baltimore Gas & Electric	456	76,564
29	Information Technology	PECO Energy Company	107, 146, 456, 920, 923	357,257
30	Legal Department Services	PECO Energy Company	146	50,880
31	Audit Services	PECO Energy Company	146	735
32	Materials	PECO Energy Company	146	29,921
33	Transmission Services	PECO Energy Company	456, 920	97,414
34	Information Technology	Pepco Holdings LLC	186, 107, 923	22,369
35	Legal Department Services	Pepco Holdings LLC	146	75,388
36	Audit Services	Pepco Holdings LLC	146	1,067
37	Materials	Pepco Holdings LLC	517, 154	1,432
38	Transmission Services	Pepco Holdings LLC	456	138,348
42

FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report

INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

Purpose

Who Must Submit

What and Where to Submit

When to Submit

Where to Send Comments on Public Reporting Burden.

GENERAL INSTRUCTIONS

EXCERPTS FROM THE LAW

GENERAL PENALTIES

FERC FINANCIAL REPORT
FERC FORM No. 1: Annual Report of
Major Electric Utilities, Licensees
and Others and Supplemental
Form 3-Q: Quarterly Financial Report